Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout201-172 STATE OF ALASKA RECEIVED
• ALA. OIL AND GAS CONSERVATION COMOION
REPORT OF SUNDRY WELL OPERATIONS APR 0 2 201)
1. Operations Performed: Abandon r Repair well r Plug Perforations r FFrforate r
Alaska Gil ten; pris. Commission
Alter Casing
r Pull Tubing 17 Stimulate - Frac r Waiver r Time Extension ,
Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Weil' •-
2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development I✓ Exp loratory r 201 - 172
3. Address: 6. API Number:
Stratigraphic r Service r
P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23037 - 60 0)
7. Property Designation (Lease Number): 8. Well Name and Number:
ADL 25649 , 1C-102L1
9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s):
none Kuparuk River Field / West Sak Oil Pool
11. Present Well Condition Summary:
Total Depth measured 10600 feet Plugs (measured) None
true vertical 3688 feet Junk (measured) None
Effective Depth measured 10566 feet Packer (measured) 2509, 6042
true vertical 3688 feet (true vertucal) 1998, 3714
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 121 16 161 161
SURFACE 6477 7.625" 6518 3801
D -SAND LINER 4524 4" 10566 3688
Perforation depth: Measured depth: 6536- 10443'
True Vertical Depth: 3744' -3685' APR 9 Zn1a
Tubing (size, grade, MD, and TVD) 3.5, L -80, 5884 MD, 3658 TVD
Packers & SSSV (type, MD, and TVD) Weatherford Dual String Packer @ 2509 MD, 1998 TVD
Baker SCR -1 Packer @ 6042 MD, 3714 TVD
No SSSV
12. Stimulation or cement squeeze summary:
Intervals treated (measured): not applicable
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure
Prior to well operation 186 67 72 -- 279
Subsequent to operation shut - in
14. Attachments 15. Well Class after work:
Copies of Logs and Surveys run Exploratory l Development _Service r Stratigraphic r
16. Well Status after work: --Oil r Gas r WDSPL r
Daily Report of Well Operations _XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
none
Contact Ian Toomey 263 -4773
Printed Name Ian Toomey Title Wells Engineer
Signature 263 -4773 Date
—, e , 3 -3v - z
_ �B APR �' b.-0/ '� /�
Form 10 404 Revised 1 1/20 11 3 K Submit Original Only
a KUP • 1C-102L1
ConocoPhillips 1 Well Attributes Max Angle & MD TD
Ala a It Wellbore API /UWI Field Name Well Status Inc] 6) MD (ftKB) Act Btm (ftKB)
500292303760 WEST SAK PROD 93.63 9,134.74 10,600.0
CarsacoPhilbps ""` Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date
'° SSSV: NONE 5 9/25/2011 Last WO: 45.31 10/13/2001
Well Conan - 1GL1, 12520122 16
: : 36 PM
scnemalk - 102 3 AUUeI Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date
Last Tag: Rev Reason: WORKOVER ninam 3/25/2012
Casing Strings
Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) .. String Wt... String ... String Top Thrd
HANGER,25 - D -SAND LINER 4 3.550 5,936.1 10,566.5 3,687.7 9.50 L -80 SLHT
Liner Details
Top Depth
(TVD) Top Inc! Nomi-.-
Top (ftKB) (ftKB) r) Item Description Comment ID (in)
t 5,936.1 3,677.8 67.91 HANGER BAKER FLANGED HOOK HANGER 5.630
CONDUCTOR, ! 1. 5,959.1 3,685.5 70.98 SWIVEL BAKER LINER SWIVEL SUB 4.000
40 s 6,043.1 3,706.2 78.15 ECP BAKER PAYZONE PACKER (20' SEAL) 3.930
6,398.8 3,741.6 87.20 ECP BAKER PAYZONE PACKER (20' SEAL) 3.930
g 6,461.9 3,743.9 88.81 SLEEVE BAKER 'CMD' SLIDING SLEEVE 3.430
II 6,503.9 3,744.5 91.24 X04.5x4 3.550
P . 10,506.9 3,686.6 88.94 X04.5x5 3.550
1 10,545.4 3,687.3 88.95 X05x3.5 3.500
GAS LIFT, ti t Perforations & Slots
2.384 Shot
Top (TVD) Btm (TVD) Dens
Top (MB) Btm (ftKB) (RKB) (ftKB) Zone Date (sh.-. Type Comment
6,536 10,443 3,743.8 3,685.3 WS D, 1C -102L1 9/28/2001 50.0 SLOTS Alternating 37' screens & 31' blank
pipe
PACKER, 2,509 Notes: General & Safety
End Date Annotation
• 7/20/2002 NOTE: MULTI - LATERAL WELL: B-SAND (1C -102), D -SAND (1C- 102L1)
It 7/14/2009 NOTE: View Schematic w/ Alaska Schematic9.0
et
GAS LIFT,
2.621
1
GAUGE, 5,794
IIMSIMIMO
INTAKE, 5.852 1
SEAL, 5,856 (~2.:7
Reduction.
5.870
MOTOR, 5.872
GAUGE, 5,880 ' <.=Zit
Centralizer, ' 1�
5,882
C
SURFAE,
. 1
41-6,518
AE.
1
Mandrel Details
Top Depth Top Port
(TVD) Inc! OD Valve Latch Size TRO Run
Stn Top (ftKB) (ftKB) 6) Make Model (!n) Sery Type Type (in) (psi) Run Date Com...
1 0 1 2,384.1 1,944.0 64.79 CAMCO KBMG 1 GAS LIFT DMY BK - 5 0.000 0.0 2/27/2012
SLOTS.
443 1
ry 2 2,621.4 2,047.1 63.76 CAMCO KBMG 1 GAS LIFT DMY BK - 5 0.000 0.0 2/27/2012
8,536 -1
D
g
D.SAND
LINER.
5,938 - 10,566 J l
-
TD (1C-102M. —
10,600
• 1C -102 and 1C -102L1 Well Work •
DATA SUMMARY
12/28/11 PRE RWO T -POT BONNET( PASSED ), T -PPPOT BONNET ( PASSED ), T -POT UPPER
BODY ( PASSED ), T -PPPOT UPPER BODY ( PASSED ), T -POT LOWER BODY ( PASSED
), T -PPPOT LOWER BODY ( PASSED ),
GLS TEST ( PASSED ), GLS -PP TEST ( PASSED ), FT -LDS ALL NORMAL.
2/6/12 BAILED FILL. PULLED SLIPSTOP @ 5784' SLM. IN PROGRESS.
2/7/12 REPLACED SOV @ 5663' RKB w/ DV, RAN PACKOFF TEST TOOL TO 5783' SLM, PASS
MITT TO 2500 PSI, PULLED TEST TOOL, EQUILIZED 4 1/2 D &D PACKK OFF ASSY', IN
PROGRESS.
2/8/12 PULLED 4 1/2 D &D PACKOFF ASSY' @ 5783' SLM, PULLED 37.44' ESP @ 5792' SLM,
LRS PUMP 155 BBLS HOT DIESEL DOWN IA & 90 BBLS HOT DIESEL DOWN TUBING,
BPV HAS BEEN CALLED TO INSTALL, JOB COMPLETE.
• •
ConocoPhiIIips Time Log & Summary
We /!view Web Reporting Report
Well Name: 1C - 102 Rig Name: NORDIC 3
Job Type: RECOMPLETION Rig Accept: 2/22/2012 2:00:00 AM
Rig Release: 3/4/2012 8:00:00 AM
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
02/21 /2012 24 hr Summary
Rig Move 1E-05A to 1C-102. Set -up Rig Mats.
12:00 16:00 4.00 MIRU MOVE DMOB P Rig Move 1E-05A to 1C-102. Stop at
1 E and Spine road access.
16:00 19:00 3.00 MIRU MOVE MOB P Standby for aircraft arrival and
departure, field crew changeouts.
19:00 23:30 4.50 MIRU MOVE MOB P Continue Rig move 1E and Spine
road access to 1C pad.
23:30 00:00 0.50 MIRU MOVE RURD P Move in mats, Build mat ramp to
climb up on double mats.
02/22/2012
Spot Rig over well. Accept Rig @ 02:00 hrs. MIRU all support equipment. Pull BPV. Pressure Test hard
line, manifold and hoses. Reverse circulate well with hot 8.6 ppg filtered seawater with 3% KCI, Monitor well.
Load and tally 3 -1/2" Drill pipe, 4 -3/4" Drill collars while waiting on filtered fluids.
00:00 03:30 3.50 MIRU MOVE RURD P Build mat ramp to climb up on
double mats. Spot and level rig on
double mats, berm up. Waiting on
rig support equipment and KWF from
MI filter skid.
Nordic Rig 3 accepted at 02:00 hrs
on 02/22/2012
03:30 12:00 8.50 MIRU MOVE RURD T Waiting on Support. Support Crew on
location to RU Hard line from Rig to
Kill Tanks. First Load of 8.6 ppg
Brine on Location.
12:00 14:15 2.25 MIRU MOVE RURD P PJSM. Starting Rigging Up hard line
and Un- loading fluid onto rig pits.
Crane on Location to Load empty
spool and spooling equipment.
14:15 15:00 0.75 MIRU RISER MPSP P PJSM. Load Lubricator and Pull
BPV.
15:00 15:30 0.50 COMPZ WELCTL PRTS P PJSM. Discuss hazard for Testing
lines. Fluid pack and PT Hard -line to
325/
15:30 16:45 1.25 COMPZ WELCTL OWFF P Call DSO and Security. Open well
and obtain Initial TBG & IAP. 690 psi
on TBG and 690 psi IA. Open Choke
and Bleed gas cap down to kill tank.
16:45 18:00 1.25 COMPZ WELCTL CIRC P Started seeing fluid back to kill tank.
Line up mud pump to reverse
circulate down IA taking returns up
tbg at 5 bpm, 300 psi. After 100 bbls
pump had 60 psi on IA and 0 on
TBG, no returns at kill tank. After
181 bbls down TBG, shut in IA and
bullheaded 109 bbls down tubing.
Page 1 of 11
• •
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
18:00 19:00 1.00 COMPZ WELCTL OWFF P Monitor well for flow. SITP after 15
mins was 270 psi. Call and discuss
results with town engineer. Monitor
well for 15 more minutes, SI TP /IAP
= 210/240 psi continue to monitor
well, Call and discuss with town
engineer about building filtered
volumes in pits and tanks.
19:00 21:00 2.00 COMPZ WELCTL KLWL P Line up and circulate another Inner
annular volume at 5 bpm, ICP 240
psi, TBG at 0 psi after 80 bbls, FCP
70 psi on IA. Shut down after 180
bbls, Bullhead 40 bbls down TBG 5
bpm at 70 psi, IA climbing from 70 to
230 psi. Shut down, SI TP /IAP=
0/250 psi. 13 bbl return to kill tank.
21:00 22:00 1.00 COMPZ WELCTL OWFF T Monitor well while building filtered
fluid volumes in pits and tanks. SI
TP /IAP= 0/240 psi after 15 mins.
T /IA= 0/240 psi after 30 minutes, gas
at surface on IA. Bleed gas from IA
slowly for 30 min, T /IA= 0/0 psi, shut
in and monitor pressures 30 mins, SI
TP /IAP= 0/0 (light vac on TBG, small
amount of steady gas from IA)
Load and Tally 3 -1/2" DP, 4 -3/4"
DC's.
22:00 00:00 2.00 COMPZ WELCTL KLWL T Wait on Filtered Seawater from MI
filter skid, Transports having trouble
loading seawater at CPF -1, traveling
to CPF -3 to load and come back to
filter skid on 1D pad. Continue to
load and tally DP and DC's.
Tubing= 0 psi, has very slight vac,
IA= 0 psig, steady small amount of
gas.
X2/23/2012
Continue to load and tally DP, DC's while waiting on fitered KWF. Take on KWF to pits. Circulate 8.6 ppg
filtered seawater. Install BPV. ND and Inspect Tree. Set Blanking Plug. NU 13 -5/8" 5M BOPE. Test BOPE
250/3000. Pull BPV and Blanking Plug. Install landing joint. BOLDS.
00:00 00:45 0.75 COMPZ WELCTL KLWL T Wait on Filtered Seawater from MI
filter skid, Transports traveling to
CPF -3 to load and come back to
filter skid on 1D pad. Continue to
load and tally DP and DC's.
Tubing= 0 psi, has very slight vac,
IA= 0 psig, steady small amount of
gas.
00:45 01:45 1.00 COMPZ WELCTL KLWL T 290 bbls filtered seawater on site, off
load to pits. 290 bbls total in pits.
Tubing= 0 psi, static IA= 0 psig,
steady small amount of gas.
Page 2 of 11
• •
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
01:45 03:45 2.00 COMPZ WELCTI KLWL T Wait on Filtered Seawater from MI
filter skid, Transports traveling to
CPF -3 to load and come back to
filter skid on 1D pad. Continue to
load and tally DP and DC's.
03:45 04:45 1.00 COMPZ WELCTI KLWL T 290 bbls filtered seawater on site, off
load to pits. 580 bbls total in pits.
Tubing= 0 psi, static IA= 0 psig,
steady small amount of gas.
04:45 07:00 2.25 COMPZ WELCTI KLWL T Wait on Filtered Seawater from MI
filter skid, Transports traveling to
CPF -3 to load and come back to
filter skid on 1D pad. Continue to •
load and tally DP and DC's.
07:00 08:00 1.00 COMPZ WELCTI KLWL P Enough fluid on location to start well
kill. Circulate 110 bbls of 8.6 ppg
KCL down TBG at 5 bpm, 60 psi, still
no returns, swap over and circulate
180 bbls down IA to flush completion
at 5 bpm, 60 psi.
08:00 08:30 0.50 COMPZ WELCTI OWFF P Monitor well for flow.
08:30 09:00 0.50 COMPZ WELCTL MPSP P PJSM. Set BPV.
09:00 11:30 2.50 COMPZ WHDBO NUND P Nipple Down Tree and hang in cellar.
Inspect Lifting threads and install
blanking plug.
11:30 11:45 0.25 COMPZ WHDBO SFTY P PJSM. Discuss hazard for NU
BOPE.
11:45 16:00 4.25 COMPZ WHDBO NUND P NU XO and 13 -5/8" 5M BOP
Equipment and riser with 2 -3/8" Solid
body rams in top set and 2 -7/8" x 5
1/2" VPR's in the lower set.
16:00 22:30 6.50 COMPZ WHDBO BOPE P Fluid Pack BOP Stack & Perform
Initial BOP Test 250/3000 psi for
Ram's, Choke Manifold, and Annular.
Tested VBR's with 3 -1/2" and 4 -1/2"
test joint and Annular with 2 -3/8" and
4 -1/2" test joint. Perform Koomey
draw down test. Audio Alarms was
also tested and Witness By AOGCC
Rep. Bob Noble. Rig down pressure
test equipment.
22:30 22:45 0.25 COMPZ WHDBO SFTY P PJSM- Discuss hazard for pulling
blankig plug and BPV.
22:45 23:15 0.50 COMPZ WHDBO MPSP P PU MU blanking plug retrieval tool,
pull blanking plug, Pull BPV. Set
Side Port Isolation sleeve.
23:15 23:30 0.25 COMPZ WHDBOSFTY P PJSM- Discuss hazards with
un- landing TBG hanger.
23:30 00:00 0.50 COMPZ WHDBO THGR P PU MU Landing Joint to Top Drive,
screw in to TBG hanger, BOLDS.
02/24/2012
Un -seat Tubing Hanger. Circulate Well. Pull Tunging Hanger to floor. RU to pull the 4 1/2" ESP /HT
Completion. TOOH with 4 1/2" Tubing while spooling up ESP /HT/TEC Cables. Lay down ESP Assembly.
Clean and Clear pipe shed. Set Wear Ring. Load and tally 2 -3/8" PH -6 Tubing. Bring in Baker equipment. PU
MU 7 -5/8" Casing Scraper / Clean Out BHA #1.
Page 3 of 11
• •
•
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
00:00 01:00 1.00 COMPZ WHDBO THGR P Attempted to pull the Tubing Hanger
free. Worked up to 80% of the
tubing tensile strength plus Top Drive
weigh (201K). Continue to work to
pull free. No -Joy. Wrap TBG head
with steam blanket, Pulled free in 20
mins at 175k, PU 7 -ft, Up wt 138k.
01:00 02:30 1.50 COMPZ WHDBO CIRC P Bullhead 200 bbls 130° filtered KWF
down the IA 4 bpm at 40 psi and 90
bbls of same filtered KWF down the
TBG 4 bpm at 40 psi. BDTD. Well on
vac. monitor well.
02:30 02:45 0.25 COMPZ WHDBO SFTY P PJSM- Discuss hazards pulling TBG
hanger to floor and ESP pulling
procedures with Centrilift reps.
02:45 04:30 1.75 COMPZ RPCOM THGR P Pull TBG hanger to floor, inspect for
re -use. Check ESP cable for
continuity. PU 1 stand of 4 -1/2" TBG.
Rig up ESP / Heat Trace and TEC
wire over sheaves to spoolers.
04:30 09:00 4.50 COMPZ RPCOM PULL P TOOH standing back 4 -1/2" TBG on
ODS spooling ESP /HT/TEC wire
laying down all jewelry as it presents
itself, tracking all clamps pulled and
pumping triple displacement on every
5 stands.
09:00 10:00 1.00 COMPZ RPCOM OTHR T Stop and Make Repairs to ESP
Spooler. The guard for the cable was
not tracking during spooling
operation.
10:00 15:00 5.00 COMPZ RPCOM PULL P Continue to TOOH standing back
4 -1/2" TBG on ODS spooling
ESP /HT/TEC wire laying down all
jewelry as it presents itself, tracking
all clamps pulled and pumping triple
displacement on every 5 stands.
Total Cannon Remove From
Completion - (452) 5' Mid Joint dual
channel, (7) 3' Mid -jt dual channel,
(4) 4' mid -jt dual channel, (12) 2'
mid-jt dual channel, (96) cross cplg
dual channel, (49) cross cplg single
channel, (1) end shoe dual channel.
(1) Motor Protectorlizer
(2) Pump Protectorlizers
15:00 18:00 3.00 COMPZ RPCOM PULD P Reached Intake Screen Section.
PJSM. "Recommended Practices for
ESP Dismantle, Inspection & Failure
Analysis (DIFA)" Start the
Dismantle Process.
18:00 20:30 2.50 COMPZ RPCOM OTHR P Clean and clear floors. Load out ESP
equipment. Bring in Baker
equipment. Change floors over to
2 -3/8" running equipment. Set Wear
Ring.
Page 4 of 11
•
• •
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
20:30 20:45 0.25 COMPZ RPCOM SFTY P PJSM- discuss hazards of running
small pipe, use dog collar for light
pipe, watch hand placement,
communication.
20:45 00:00 3.25 0 3,171 COMPZ RPCOM PULD P PU MU 7 -5/8" Casing Scraper /
Clean Out Assembly BHA #1-
Muleshoe, 2 -3/8" PH -6 tbg (145 jts),
XO, P x P XO, 7 -5/8" Casing
Scraper, Bit Sub, 4 -3/4" Lubricated
Bumper Sub, 4 -3/4" Oil Jar, 4 -3/4"
Drill collars (6 jts), 4 -3/4" Intensifier.
02/25/2012
PU MU 7 -5/8" Casing Scraper / Clean Out Assembly BHA #1. Clean out / Fluff and Stuff "B" sand liner to
_10,500 -ft. TOOH with BHA #1.
00:00 02:00 2.00 3,171 4,649 COMPZ RPCOM PULD P Continue to PU MU 7 -5/8" Casing
Scraper / Clean Out Assembly BHA
#1- Muleshoe, 2 -3/8" PH -6 tbg (jts
100 thru 145)
02:00 03:00 1.00 4,649 4,649 COMPZ RPCOM OTHR P Change over floors.
03:00 04:30 1.50 4,649 4,870 COMPZ RPCOM PULD P PJSM- Continue MU BHA #1 - XO, P
x P XO, 7 -5/8" Casing Scraper, Bit
Sub, 4 -3/4" Lubricated Bumper Sub,
4 -3/4" Oil Jar, 4 -3/4" Drill collaars (6
jts), 4 -3/4" Intensifier.
04:30 08:00 3.50 4,870 7,066 COMPZ RPCOM TRIP P TIH with BHA #1 on 3 -1/2" Drill Pipe,
slowing down thru hook hanger at
5,936 -ft and SCR -1 liner top packer
at 6,042 -ft
08:00 08:45 0.75 7,066 7,066 COMPZ RPCOM CIRC P Stop at 7,066 -ft and Circulate one
Annular Volume (190 bbls) at 4
bpm, 40 psi. Pumped 143 bbls and
Lost 250 bbls due to the well being
on a vac.
08:45 12:00 3.25 7,066 10,501 COMPZ RPCOM TRIP P Continue in Hole with 7 5/8" Scraper
and Mule shoe Assembly
12:00 17 :00 5.00 10,501 4,905 COMPZ RPCOM TRIP P No problem working down to
10,500 -ft with Scraper & Mule Shoe
Assembly. Up Wt 145k / Dn Wt
67k. Start TOOH standing back Drill
Pipe and Laying down 2 3/8" PH6
TBG and Scraper Assembly.
17:00 19:00 2.00 4,905 4,905 COMPZ RPCOM OTHR P Secure well. Crane on site. PJSM-
change out ESP cable spools old for
new, off load heat trace cable and
spooler.
19:00 20:00 1.00 4,905 4,649 COMPZ RPCOM PULD P Lay down BHA #1- Intensifier, DC's,
Oil Jars, Bumper Sub, Bit Sub, &
7 -5/8" Casing Scraper, XO, XO.
20:00 21:00 1.00 4,649 4,649 COMPZ RPCOM OTHR P Change over floors to 2 -3/8"
equipment.
21:00 00:00 3.00 4,649 2,823 COMPZ RPCOM TRIP P Single down 2 -3/8" PH6 tbg from
4,649 -ft still pumping triple
displacement every 5 stds, 20 bbls
every hour.
Page 5 of 11
• •
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
02/26/2012 24 hr Summary
TOOH with BHA #1. MU & TIH with 7 -5/8" Lock -set RBP / Test Plug Assembly BHA #2. Test 7 -5/8" Casing
1500 psi, Passed. TOOH with BHA #2. Single down and kick out 4 -1/2" De- completion. Load, drift and tally
3 -1/2" ESP completion w/ Feed -thru packer.
00:00 03:00 3.00 2,823 0 COMPZ RPCOM TRIP P Continue to single down 2 -3/8" PH6
tbg from 2,823 -ft.
03:00 03:45 0.75 0 0 COMPZ RPCOM OTHR P Change over floors to 3 -1/2"
equipment. Load out PH6 tbg. clean
and clear floors.
03:45 04:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discuss hazards of MU and
running RBP and Test plug. Cold
weather assessment for anyone
working outside -53° wind chill,
Loader shut down due to -37°
ambient temperatures.
04:00 04:30 0.50 0 35 COMPZ RPCOM PULD P PU MU 7 -5/8" RBP / Test Plug
Assembly BHA #2- 7 -5/8" Model "G"
Lock set RBP, Model "L" Retrieving
head, 7 -5/8" Retrievamatic Test
PKR.
04:30 08:30 4.00 35 5,812 COMPZ RPCOM TRIP P TIH with BHA #2 (test packer &
RBP) on 3 -1/2" Drill Pipe down to
5,812 -ft
08:30 09:00 0.50 5,812 5,812 COMPZ RPCOM PLUG P Set RBP at 5,812 -ft. Release and
PUH one stand, and set Test
Packer.
09:00 09:45 0.75 5,812 5,812 COMPZ RPCOM PRTS P RU testing equipment. PT between
RBP and Test Packet to 1500 psi for
15 minutes. Bleed down pressure
and Pressure test 7 5/8" CSG to
1500 psi for 15 minutes. Both test
passed.
09:45 10:00 0.25 5,812 5,812 COMPZ RPCOM PLUG P Release Test Packer, PUH one
stand, RIH, latch and release RBP
and let elements relax.
10:00 14:00 4.00 5,812 0 COMPZ RPCOM TRIP P TOON w/ RBP and Test Packer.
14:00 14:30 0.50 0 0 COMPZ RPCOM PULD P Lay Down Test Packer and RBP and
Un -load from pipe shed.
14:30 16:30 2.00 0 0 COMPZ RPCOM PULD P Kick out un- needed drill pipe and
PH6 2 3/8" tubing. Load 3 1/2"
completion equipment.
16:30 21:00 4.50 0 5,830 COMPZ RPCOM TRIP P TIH with 64 stands of 4 1/2"
De- completion
21:00 00:00 3.00 5,747 2,790 COMPZ RPCOM TRIP P TOOH sideways laying down TBG
and un- loading to secondary
containment to 2,584 -ft
02/27/2012
Continue to single down and kick out 4 -1/2" De- completion. Pull Wear Ring. Slip and Cut. Wait on Weather.
Load, drift and tally 3 -1/2" ESP completion. Run TTC -ESPCP 3 -1/2" Tubing Completion with Feed -thru
Packer.
00:00 02:30 2.50 2,790 0 COMPZ RPCOM TRIP P TOOH sideways laying down TBG
and un- loading to secondary
_ containment. Pull Wear Ring.
02:30 03:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM- hazards during slip and cut
operations.
03:00 05:00 2.00 0 0 COMPZ RPCOM SLPC P Slip and Cut 84 -ft Drill Line
Page 6 of 11
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• •
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
05:00 06:30 1.50 0 0 COMPZ RPCOM OTHR P Continue to load, drift and tally 3 -1/2"
completion equipment, review
completion tally and running order.
06:30 13:00 6.50 0 0 COMPZ RPCOM OTHR T Shut down Loader operation due to
cold weather condition -38 deg.
13:00 13:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discuss hazards with
handling and running ESP
completion with Centrilift and
Weatherford Reps.
13:15 16:15 3.00 0 43 COMPZ RPCOM PULD P PU Motor centralizer, welllift sensor
and motor. PU gear reduction unit
and MU to motor section and Service
same. MU motor lead extension
cable and TEC wire.
16:15 17:15 1.00 43 85 COMPZ RPCOM RCST P Start Lowering ESP into well while
attaching the MLE cable to the ESP
assembly. Stop and Install the
WeIllift discharge gauge unit and
connect the TEC wire from the motor
gauge unit.
17:15 19:30 2.25 85 85 COMPZ RPCOM RCST T Machined channel for #1 size cable
not wide enough on DGU,
disassemble from string, off load to
Centrilift Rep. truck, Centrilift to
repair off site.
19:30 19:45 0.25 85 85 COMPZ RPCOM SFTY P PJSM- Discuss hazards with
handling and running ESP
completion with Centrilift reps and
Nordic night crews. Review running
order.
19:45 21:15 1.50 85 185 COMPZ RPCOM RCST P MU DGU to completion string and
continue with Install of the WeIllift
discharge gauge unit and connect
the TEC wire from the motor gauge
unit. Installed 2 ea. 1 -1/2" SS flat
bands, 1 above and 1 below DGU to
hold ESP cable in channel. TIH 4 jts
and MEG cable, all good as per
Centrilift rep.
21:15 00:00 2.75 185 2,182 COMPZ RPCOM RCST P TIH with 3 -1/2" ESP completion
installing Cannon Clamps every other
collar keeping accurate account of all
clamps installed. MEG wire at jt #36
at 1,182 -ft, jt #68 at 2,182 -ft.
02/28/2012
Continue to Run TTC -ESPCP 3 -1/2" Tubing Completion with Feed -thru Packer. Make Final Splice. Land
Tubing Hanger. Test Pack -off. Continue 20 bbls down well every hour while waiting on weather.
00:00 02:00 2.00 2,182 3,365 COMPZ RPCOM RCST P Continue to TIH with 3 -1/2" ESP
completion installing Cannon Clamps
every other collar to first GLM, then
every collar to packer keeping
accurate account of all clamps
installed.
02:00 07:00 5.00 3,365 3,390 COMPZ RPCOM PULD P PU & MU Weatherford WFT
Hydrow -II packer, check integrity,
MU cable assembly through packer,
check integrity.
Page 7 of 11 1
• •
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
07:00 12:00 5.00 3,390 32 COMPZ RPCOM RCST P Continue to TIH with 3 -1/2" ESP
completion installing Cannon Clamps
every collar to top GLM, then every
other collar to surface keeping
accurate account of all clamps
installed. Up wt 77k, Dn wt 58k
12:00 15:00 3.00 32 32 COMPZ RPCOM OTHR P PU TBG Hanger and install
penetrators. Space out and make
final splice.
15:00 16:00 1.00 0 0 COMPZ RPCOM HOSO P Land TBG hanger 120k Up wt, 65k
Dn wt. RILDS
Final Clamp count:
102 ea Cannon Single channel cross
clamps (every other collar MLE to
surface)
4 ea Cannon Seal clamps (across
Tandam seal sections)
2 ea 1 -1/2" SS Flat bands (lea.
above and below DGU)
16:00 17:00 1.00 0 0 COMPZ RPCOM PRTS P PT Inner and Outer Hanger Pack offs
at 250/5,000 psi. Pull ISO sleeve
and reinstall landing joint.
17:00 00:00 7.00 0 0 COMPZ RPCOM PULD T Change over floors and single down
3 -1/2" DP in mouse hole to pipe
shed (23 stands) Continue to
PP
um bbls down Tubing and 10
bbls down IA every hour for hole fill
while waiting on weather.
32/29/2012
Continue 20 bbls down well every hour while waiting on weather. Review well program, audit rig for repair and
maintenance.
00:00 06:00 6.00 0 0 COMPZ RPCOM CIRC T Continue to single down remainder of
3 -1/2" DP in mouse hole to pipe
shed. Continue to pump 10 bbls
down Tubing and 10 bbls down IA
every hour for hole fill while waiting
on weather.
Review well program, audit rig for
repair and maintenance.
06:00 12:00 6.00 0 0 COMPZ RPCOM CIRC T Continue to pump 10 bbls down
Tubing and 10 bbls down IA every
hour for hole fill while waiting on
weather.
Review well program, audit rig for
repair and maintenance.
Page 8 of 11
•
• •
Time Logs
Date From To Dur S. Death_, E. Depth Phase Code Subcode T Comment
12:00 18:00 6.00 0 0 COMPZ RPCOM CIRC T Continue to pump 10 bbls down
Tubing and 10 bbls down IA every
hour for hole fill while waiting on
weather. Temperature reached -35°
for 3 hrs during the afternoon, but still
unable to operate. Everybody is on
call, standing by..
Review well program, audit rig for
repair and maintenance.
18:00 00:00 6.00 0 0 COMPZ RPCOM CIRC T Continue to pump 10 bbls down
Tubing and 10 bbls down IA every
hour for hole fill while waiting on
weather.
Review well program, audit rig for
repair and maintenance.
03/01/2012
Continue 20 bbls down well every hour while waiting on weather. RU Slickline. Freeze Protect Tubing. Set
WRP and Test. Load IA with 60 bbls Gelled Diesel, IA pressured up. Confer with town engineer. Set WF
Hydrow -II Packer.
00:00 06:00 6.00 0 0 COMPZ RPCOM CIRC T Continue to pump 10 bbls down
Tubing and 10 bbls down IA every
hour for hole fill while waiting on
weather.
Review well program, audit rig for
repair and maintenance.
06:00 14:00 8.00 0 0 COMPZ RPCOM CIRC T Continue to pump 10 bbls down
Tubing and 10 bbls down IA every
hour for hole fill while waiting on
weather.
Review well program, audit rig for
repair and maintenance.
14:00 14:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Discuss hazards with getting
back to work after extended period of
cold weather.
14:15 15:30 1.25 0 0 COMPZ RPCOM OTHR P Roudup Slickline crew, ETD and
WRP. Off load 3 -1/2" DP. Load
Slickline lubricator all ready on site.
15:30 15:45 0.25 0 0 COMPZ RPCOM SFTY P Discussed hazards of Slickline rig
up, running WRP.
15:45 18:00 2.25 0 0 COMPZ RPCOM SLKL P RU HES Slickline unit 214, pressure
test equipment 500 psi.
18:00 19:15 1.25 0 2,623 COMPZ RPCOM SLKL P RIH w/ 3" OK -1 and JK running tool,
locate GLM #1 at 2,623- ft- POOH to
change out tools. Pupm 25 bbls
diesel down TBG.
19:15 20:45 1.50 0 2,654 COMPZ RPCOM SLKL P RIH w/ 2.78" OD WRP on HES
1- 11/16" Down hole Power Unit, set
top of WRP at 2,650 -ft- POOH,
change out tools.
20:45 21:15 0.50 0 2,650 COMPZ RPCOM SLKL P RIH w/ 2.75" Catcher ( "G" FN, 29"
OAL) on 3" GS; set at 2,648 -ft.
POOH (Noticed fluid level at
- 1,050 -ft)
Page 9 of 11
•
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
21:15 21:45 0.50 0 0 COMPZ RPCOM PRTS P Test WRP to 500 psi (9.8 bbls to fill
TBG) lost 100 psi in 15 min. bleed to
0 psi to get air out of system.
21:45 22:15 0.50 0 0 COMPZ RPCOM PRTS P Stand lubricator back, RU head pin
and test equipment, retest WRP to
500 psi, good
22:15 23:45 1.50 0 0 COMPZ RPCOM CIRC P Line up on IA, pressured up to 500
psi immediatly, Check and remove
ice plug from hose, circulate gelled
diesel down IA 3 bpm at 70 psi,
pressure building at 60 bbls, shut
down at 1000 psi, bleeds back very
slowly, bleed back to 0 psi and
pressure back up to 1000 psi, Confer
with town engineer, Bleed IA to 0 psi.
line up pump to TBG.
23:45 00:00 0.25 0 0 COMPZ RPCOM PACK P Initiate packer setting, pressure TBG
to 3000 psi, pressure dropped to
2700 psi in 10 min, bump TBG
pressure back to 3000 psi
33/02/2012
Set WF Hydrow -II Packer. Pull DV in Top GLM at 2,384 -ft. Circulate TBG / IA 110 bbls Gelled Diesel. Set DV
at 2,384 -ft. Pressure test IA 1500 psi. RD Slickline. De- pressure IA per Centrilift schedule. RD landing Joint.
Drain BOP stack. Install TWCV. ND BOPE. Check Cable integrity. NU Tubing head adapter and Tree. Test
tree. Test Hanger void /pack -off. Make final cable integrity checks. Pull TWCV, Install BPV. Clean cellar. Move
postponed while waiting on weather.
00:00 01:00 1.00 0 0 COMPZ RPCOM PACK P Continue setting packer, TBG at
3000 psi, TBG at 2950 psi in 20
minutes, packer set, bleed TBG to 0
psi, RD test equipment.
01:00 02:00 1.00 0 2,387 COMPZ RPCOM SLKL P PJSM- RU lubricator and RIH w/ 3"
OK -1 & 1.25" JDC; latch at 2,387 -ft
and POOH w/ DV on BK, Change
out Tools.
02:00 03:00 1.00 0 0 COMPZ RPCOM CIRC P Circulate 110 bbls gelled diesel down
IA taking returns thru choke to kill
tank 2 bpm at 150 psi ICP, 100 psi
FCP.
03:00 03:30 0.50 0 2,387 COMPZ RPCOM SLKL P RIH w/ 3" OK -1 & DV on BK; set at
2,387 -ft- POOH
03:30 04:30 1.00 0 0 COMPZ RPCOM SLKL P PJSM- Discuss hazards of rigging
down Slickline equipment. RD
Slickline.
04:30 05:00 0.50 0 0 COMPZ RPCOM PRTS P Pressure test IA 1500 psi, chart 30
minutes, good.
05:00 08:00 3.00 0 0 COMPZ RPCOM PRTS P Start Centrilift time /pressure
schedule for bleeding IA to 0 psi. RD
test equipment.
08:00 09:00 1.00 0 0 COMPZ WHDBO THGR P Lay down landing joint. Set TWCV.
09:00 11:00 2.00 0 0 COMPZ WHDBO NUND P ND BOPE
11:00 12:00 1.00 0 0 COMPZ WHDBO DHEQ P Make ESP cable integrity tests,
good.
12:00 13:30 1.50 0 0 COMPZ WHDBO NUND P NU Tree.
13:30 14:30 1.00 0 0 COMPZ WHDBO DHEQ P Make final ESP cable integrity tests,
all systems go. All completed forms
and readings in well file and folder.
Page 10 of 11
" • •
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
14:30 15:30 1.00 0 0 COMPZ WHDBO PRTS P Pressure test tree 5000 psi 15 min
on chart. test tubing hanger void
5000 psi. RD test equipment.
15:30 16:30 1.00 0 0 COMPZ WHDBO THGR P Pull TWCV and install 3" Type "H"
BPV
16:30 18:30 2.00 0 0 COMPZ MOVE OTHR P Off load fluids, load tools. Clean and
prep cellar for move. preform pre
move warm up procedures for rig
hydraulics.
18:30 00:00 5.50 0 0 COMPZ MOVE MOB T Cold Weather Shutdown procedures
back in effect. Wait on Weather.
Review well program, audit rig for
repair and maintenance.
33/03/2012
Move postponed while waiting on weather. Review well program, audit rig for repair and maintenance.
00:00 06:00 6.00 0 0 COMPZ MOVE MOB T Continue to wait on weather over well
1C-102, continue to warm rig
hydraulics. Review well program,
audit rig for repair and maintenance.
06:00 18:00 12.00 0 0 COMPZ MOVE MOB T Continue to wait on weather over well
1C -102. Review well program, audit
rig for repair and maintenance.
18:00 00:00 6.00 0 0 COMPZ MOVE MOB T Continue to wait on weather over well
1C -102. Review well program, audit
rig for repair and maintenance.
03/04/2012
Move postponed while waiting on weather. RDMO Nordic Rig 3.
00:00 04:00 4.00 0 0 COMPZ MOVE MOB T Continue to wait on weather over well
1C -102. Review well program, audit
rig for repair and maintenance.
04:00 08:00 4.00 0 0 COMPZ MOVE MOB P Cold weather restrictions lifted. start
warming, circulating rig hydraulics,
rolling tires. finish building ramp to
move off well 102 and over well 109.
Released Nordic 3 at 08:00 hrs on
3 -4 -12
Page 11 of 11
.
.
MICROFILMED
07/25/06
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc
J ?> f,j' ~ v ÀJjJj '>
DATA SUBMITTAL COMPLIANCE REPORT
1 0/22/2003
Permit to Drill 2011720
Well Name/No. KUPARUK RIV U WSAK 1C-102L1
Operator CONOCOPHILLIPS ALASKA INC
ÇfC-Lt:l Jf?~~~
API No. 50-029-23037-60-00
MD
10600,/
TVD
3688 / Completion Date 10/13/2001 r-
Completion Status
1-01L
Current Status 1-01L
UIC N
----- - -- --~
~---~---- ------
REQUIRED INFORMATION
Mud Log No
Samples No
Directional Survey
:Nf}Y~ ~---
_-_n__-~---
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
(data taken from Logs Portion of Master Well Data Maint)
_c~
Logl
Data
Type.
~
__D
¥
I
I
I
~
Well Cores/Samples Information:
Digital
Med/Frmt
D
C
Log Log Run
Scale Media No
1
1
Interval OH I
Start Stop CH Received
241 10538 Open 217/2002
Comments
5800
10600 Case 11/1/2002
Digital Data: Rate of
Penetration, Dual Gamma
Ray, Electromagnetic
Wave Resistivity I
--~
Name
Interval
Start Stop
Sent
Received
Sample
Set
Number Comments
ADDITIONAL INFORMATION
Well Cored? Y 11iJ
Chips Received? ~......
Daily History Received?
cDN
@N
~~-
Formation Tops
Analysis
Received?
.::Y~
---~-
----- - ---
Comments:
Compliance Reviewed By: ~ Date: -1~1I ~'j, ~ .,,-
{
(
ao/-/ 7 ~
IlaeoL(
WELL LOG TRANSMITTAL
To:
State of Alaska
Alaska Oil and Gas Conservation Corom.
Attn.: Lisa Weepie
333 West 7th Avenue, Suite 100
J\nchorage,Alaska 99501
November 01,2002
RE:
MWD Fonnation Evaluation Logs: lC-102 Ll,
AK-MM-III44
The technical data listed below is being submitted herewith. Please address any problems or concerns
to the attention of:
Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., J\nchorage, AK 99518
lC-lO2 Ll:
Digital Log Images:
50-029-23037-60
1 CD RotTI
~~
RECEIVED
NOV 0 1 2002
Ala8fca on & Gas Cons. Commi8lion
Anchorage
("
(
"r~....ilN. .....'..'.'...l....!~....'..'-.."o.'.,.'..1". "7"1,'.. .'. "':~,,",\""
" :":":,,"'!¿~¡::;,,(,:\,C>t
WELL LOG TRANSMI1T AL
To:
State of Alaska
Alaska Oil and Gas Conservation Co.
Attn.: Lisa Weepie
333 West 7th Avenue, Suite 100
J\nchorage,Alaska 99501
February 06, 2001
RE:
MWD Fonnation Evaluation Logs
lC-102 Ll,
AK-MM-ll144
1 LDWG fonnatted Disc with verification listing.
AJPI#: 50-029-23037-60
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL
LETTER TO THE ATTENTION OF:
Sperry-Sun Drilling Service
Attn: Jim Galvin
6900 Arctic Blvd.
J\nchorage, Alaska 99518
Si~d JJc¿~
Date:
REceIVED
FEB 0 ì 2002
AlasIca Oil & Gas f'A_- ('~-
~ W""""IIImUD
( STATE OF ALASKA (-
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of well
Oil 0 Gas D
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510-0360
4. Location of well at surface
Suspended
D
Abandoned D
Classification of Service Well
Service D
, V::.x:¿.~
V~1fÐ
Suf'6( JJ 1\
~- H~" "
.' -,
1420' FNL, 600' FWL, Sec. 12, T11N, R10E, UM (ASP: 561606, 5968814)
-,
At Top Producing Interval " ,-, ;
57' FNL, 2400' FEL, Sec. 11, T11 N, R10E, UM (ASP: 558595, 597053) ,- _/..I),-J3~()j "
At Total Depth : ,,__ìh..___- :
902' FSL, 2371' FEL, Sec. 11, T11N, R10E, UM (ASP: 558662, 5965832) '_,'d-, ',-" - ..,,' -
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No.
RKB 41 feet ADL 25649 ALK 467
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband.
August 18, 2001 September 15, 2001 October 13, 2001
17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey
10600' MD 1 3688' TVD N/A YES 0 No D
22. Type Electric or Other Logs Run
GR/Res
23.
7. Pennit Number
201-172
8. API Number
-,~-.;...",~,.
50-029-23037-60
9. Unit or Lease Name
" --
Kuparuk River Unit
10. Well Number
1C-102L 1
11. Field and Pool
Kuparuk River Field
West Sak Oil Pool
15. Water Depth, if offshore 16. No. of Completions
(P&A'd) N/A feet MSL 1
20. Depth where SSSV set 21. Thickness of Pennafrost
N/A feet MD 2025'
GRADE
H-40
L-80
L-80
L-80
CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
TOP BOTTOM
Surface 158'
Surface 6518'
5936' 10566'
6042' 10550'
CEMENTING RECORD
432 sx AS I
660 sx ASLite, 275 sx Class G
AMOUNT PULLED
CASING SIZE
WT. PER FT.
62.5#
29.7#
9.5#
9.5#
HOLE SIZE
16"
24"
7.625"
9.875"
4" X 4.5"
4" X 4.5"
6"
6"
24. Perforations open to Production (MD + TVD of Top and Bottom and
interval, size and number)
25.
SIZE
screen
screen
4.5"
TUBING RECORD
DEPTH SET (MD)
5894'
PACKER SET (MD)
N/A
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
9357' - 8853' 69 bbls 1 0% HCI acid
8853'- 7541' 52 bbls 10% HCI acid
7541'-6535' 57 bbls HCI acid
No perfs - pre-pack screens in horizontal laterals
26.
27.
Date First Production
11/22/2001
PRODUCTION TEST
Method of Operation (Flowing, gas lift, etc.)
Flowing - shares production with 1C-102
Production for OIL-BBL GAS-MCF
Test Period> 1029 95
Calculated OIL-BBl GAS-MCF
24-Hour Rate> 171.5 16
CORE DATA
Date of Test
11/29/2001
Flow Tubing
Press. 368 psi
28.
Hours Tested
4
Casing Pressure
not available
Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.
N/A
Form 10-407 Rev. 7-1-80
CONTINUED ON REVERSE SIDE
WATER-BBl
67
WATER-BBL
11
CHOKE SIZE GAS-Oil RATIO
100 92
OIL GRAVITY - API (corr)
not available
RECEIVED
fi1.' F C') 'a 0 ¡OJ 0 0 1
Ii,} '- !. J.. ð L
,
---
¡~iaska Oil & Gas Cons. Commission
" ,I,
"
...
Submit in duplicate
r"~'-~ \G\i , f\I l
'¡ ì" I. ,,";, j
, }~". . ',..~¡: ¡ :\11 I.,~. R B OMS B F L
,."",~\ï ~" \\;,~\-
(, D$C 2 8 200/
"
29.
30.
GEOLOGIC MARKER~
FORMATION TESTS
NAME
MEAS.DEPTH
TRUE VERT. DEPTH
Include interval tested, pressure data, all fluids recovered and gravity.
GOR, and time of each phase.
Top West Sak Sand 6270' 3737
West Sak B j 10600' 3688'
Base West Sak Sand 10600' 3688'
N/A
31. LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey
32. I h:rebY/?"hat tha ~"OWlng Is t and oo"%. ;::;,;; knowledge.
Signed;ø:~ TIlle Drilling Enolneering SupelVlsor
Chuck Mallary
Questions? Call Steve McKeever 265-6826
Date ~
Prepared by Sharon Allsup-Drake
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and
leases in Alaska.
Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water
supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other
spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in
item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each
additional interval to be separately produced, showing the data pertinent to such interval.
Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location
of the cementing tool.
~~~-~:O~:~~:P~:i~.peration: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water 1'r{~d~liWD
Item 28: If no cores taken, indicate "none".
DEC 1 8 2001
Form 10-407
ORIGINAL
Alaska Oil & Gas Cons. Commission
Anchorage
(
(
07 -Nov-01
AOGCC
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
Definitive
Re: Distribution of Survey Data for Well 1 C-1 02 L 1
aOI-'7~
Dear Dear Sir/Madam:
Enclosed are two survey hard copies and 1 disk
Tie-on Survey: 5,854.56' MD
Window / Kickoff Survey 5,941.00' MD (if applicable)
Projected Survey: 10,600.00' MD
Please call me at 273-3545 if you have any questions or concerns.
Regards,
William T. Allen
Survey Manager
Attachment(s)
r~ECEJ\/ED
NOV 1 3 2001
AJaska OU & Gas Cons. CommiSSion
Anchorage
~
DEFINITIVE
'.~.
Kuparuk River Unit
North Slope, Alaska
Kuparuk 1C, Slot 1C-102
1C-102L 1
Job No. AKMM11144, Surveyed: 15 September, 2001
.~.
SURVEY REPORT
7 November, 2001
Your Ref: API 500292303760
Surface Coordinates: 5968813.50 N, 561606.18 E (70019' 31.2102" H, 149030' 01.5791" W)
Surface Coordinates relative to Project H Reference: 968813.50 N, 61606.18 E (Grid)
Surface Coordinates relative to Stucture Referance: 297.32 H, 763.45 W (True)
Kelly Bushing: 101.85ft above Mean Sea Level
~
spe"""""V-5UIl
DFlILLING SERVICES
A Halliburton Company
Survey Ref: 5vy9620
Sperry-Sun Drilling Services
Survey Report for 1C-102L1 DEFiNIT\V
Your Ref: API 500292303760
Job No. AKMM11144, Surveyed: 15 September, 2001
North Slope, Alaska
Kuparuk River Unit Kuparuk 1 C
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Inct Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (It) (ft) (°/1 OOft)
5854.56 68.730 211.780 3546.30 3648.15 1721.55 N 2824.81 W 5970511.80 N 558767.33 E -1721.55 Tie on Point
...-- 5941.00 68-560 212.760 3577.78 3679.63 1653.48 N 2867.79 W 5970443.38 N 558724.91 E 1.074 -1653.48 Window Point
6008.45 77.600 212.990 3597.39 3699.24 1599.35 N 2902.78 W 5970388.96 N 558690.37 E 13.406 -1599.35 -~-
---- 6057.20 79.160 213.150 3607.21 3709.06 1559.33 N 2928.84 W 5970348.73 N 558664.64 E 3.216 -1559.33
6088.34 81.410 212.730 3612.47 3714.32 1533.57 N 2945.53 W 5970322.84 N 558648.16 E 7.347 -1533.57
6152.25 82.910 201.480 3621.21 3723.06 1477.31 N 2974.31 W 5970266.34 N 558619.84 E 17.595 -1477.31
6185.21 83.280 197.790 3625.17 3727.02 1446.49 N 2985.31 W 5970235.43 N 558609.10 E 11.171 -1446.49
6247.28 83.220 186.120 3632.49 3734.34 1386.30 N 2998.05 W 5970175.14 N 558596.85 E 18.671 -1386.30
6291.93 87.230 184.530 - 3636.21 3738.06 1342.00 N 3002.18 W 5970130.81 N 558593.08 E 9.656 -1342.00
6342.07 88.950 186.850 3637.88 3739.73 1292.14 N 3007.15 W 5970080.91 N 558588.53 E 5.758 -1292.14
6393.46 86.800 185.760 3639.79 3741.64 1241.10 N 3012.79 W 5970029.83 N 558583.31 E 4.690 -1241.10
6436.89 88.280 183.130 3641.65 3743.50 1197.85 N 3016.15 W 5969986.55 N 558580.30 E 6.944 -1197.85
6482.19 89.570 178.510 3642.50 3744.35 1152.58 N 3016.80 W 5969941.27 N 558580.02 E 10.587 -1152.58
6531.22 91.420 178.360 3642.08 3743.93 1103.57 N 3015.46 W 5969892.27 N 558581.76 E 3.786 -1103.57
6577.28 91.720 178.060 3640.82 3742.67 -1057.55 N 3014.02 W 5969846.27 N 558583.58 E 0.921 -1057.55
6625.09 91.910 177.520 3639.30 3741.15 1009.80 N 3012.18 W 5969798.53 N 558585.81 E 1.197 -1009.80
6667.16 91.480 178.200 3638.06 3739.91 967.78 N 3010.61 W 5969756.53 N 558587.73 E 1.912 -967.78
6720.33 92.520 180.770 3636.20 3738.05 914.65 N 3010.13W 5969703.40 N 558588.64 E 5.212 .914.65
6761.23 92.590 180.740 - 3634.38 3736.23 873.79 N 3010.67 W 5969662.54 N 558588.44 E 0.186 -873.79
6815.84 92.150 180.010 3632.12 3733.97 819.23 N 3011.02W 5969607.98 N 558588.53 E 1.560 -819.23
(~
6856.29 92.280 180.660 3630.56 3732.41 778.81 N 3011.26 W 5969567.56 N 558588.63 E 1.638 -778.81
6909.26 89.450 177.720 3629.76 3731.61 725.86 N 3010.51 W 5969514.62 N 558589.81 E 7.703 -725.86
6950.51 91.170 177.640 3629.53 3731.38 684.65 N 3008.84 W 5969473.42 N 558591.82 E 4.174 -684.65
7004.52 91.050 178.360 3628.49 3730.34 630.68 N 3006.96 W 5969419.47 N 558594.15 E 1.351 -630.68
7045.00 92.210 179.500 3627.34 3729.19 590.23 N 3006.20 W 5969379.03 N 558595.23 E 4.017 -590.23
7099.85 91.970 177.450 3625.34 3727.19 535.43 N 3004.74 W 5969324.25 N 558597.14 E 3.761 -535.43
7140.01 91.910 176.490 3623.98 3725.83 495.35 N 3002.62 W 5969284.19 N 558599.59 E 2.394 -495.35
7194.69 91.850 - 176.870 3622.18 3724.03 440.80 N 2999.46 W 5969229.66 N 558603.21 E 0.703 -440.80
7236.31 91.290 176.840 3621.04 3722.89 399.25 N 2997.17 W 5969188.13 N 558605.83 E 1.347 -399.25
7289.03 90.920 176.470 3620.03 3721.88 346.63 N 2994.10 W 5969135.54 N 558609.34 E 0.992 -346.63
---------
7 November, 2001 - 13:25
Page 2 of 6
DrlllQ(Jest 2.00.09.003
- Sperry-Sun Drilling Services .
Survey Report for 1C-102L 1
Your Ref: AP/500292303760
Job No. AKMM11144, Surveyed: 15 September, 2001
North Slope, Alaska
Kuparuk River Unit Kuparuk 1 C
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft)
7338.26 91.720 176.190 3618.89 3720.74 297.52 N 2990.95 W 5969086.45 N 558612.89 E 1.722 -297.52
7383.80 90.430 179.030 3618.04 3719.89 252.03 N 2989.05 W 5969040.98 N 558615.16 E 6.848 -252.03
7429.89 89.570 178.600 3618.04 3719.89 205.95 N 2988.10 W 0 5968994.91 N 558616.49 E 2.086 -205.95 -- .
'-- 7478.37 89.820 177.930 3618.30 3720.15 157.49 N 2986.63 W 5968946.4 7 N 558618.36 E 1 .475 -157.49
- 7523.13 89.510 178.000 3618.56 3720.41 112.76 N 2985.04 W 5968901.75 N 558620.32 E 0.710 -112.76 J
7572.97 89.570 179.470 3618.96 3720.81 62.94 N 2983.94 W 5968851.94 N 558621.83 E 2.952 -62.94
7617.94 90.000 183.470 3619.13 3720.98 17.99 N 2985.09 W 5968806.99 N 558621.04 E 8.946 -17.99
7663.43 90.310 184.120 3619.00 3720.85 27.40 S 2988.10 W 5968761.57 N 558618.40 E 1.583 27.40
7708.71 93.450 185.500 3617.52 3719.37 72.49 S - 2991.90 W 5968716.45 N 558614.98 E 7.574 72.49
7763.26 92.030 186.070 3614.91 3716.76 126.69 S 2997.39 W 5968662.20 N 558609.93 E 2.805 126.69
7805.34 90.370 185.260 3614.03 3715.88 168.56 S - 3001.54 W 5968620.31 N 558606.12 E 4.389 168.56
7857.06 90.680 185.300 3613.55 3715.40 220.06 S 3006.30 W 5968568.77 N 558601.79 E 0.604 220.06
7900.44 90.920 184.840 3612.95 3714.80 263.26 S 3010.13 W 5968525.53 N 558598.31 E 1.196 263.26
7952.17 90.740 185.350 3612.20 3714.05 314.78 S 3014.73 W 5968473.98 N 558594.14 E 1.045 314.78
7995.85 90.550 -184.750 3611.71 3713.56 358.29 S 3018.57 W 5968430.44 N 558590.65 E 1 .441 358.29
8046.69 90.920 185.290 3611.06 3712.91 408.93 S 3023.02 W 5968379.76 N 558586.62 E .1.287 408.93
8095.35 91.050 1 84.450 3610.22 3712.07 457.41 S 3027.15 W 5968331.26 N 558582.89 E 1.747 457.41
8141.79 91.110 184.110 3609.34 3711.19 503.71 S 3030.62 W 5968284.93 N 558579.80 E 0.743 503.71
8189.24 91.230 184.330 3608.38 3710.23 551.02S 3034.11 W 5968237.59 N 558576.70 E 0.528 551.02
8235.98 90.980 183.680 3607.47 3709.32 597.64 S 3037.37 W 5968190.95 N 558573.82 E 1 .490 597.64
-'-
8277.50 90.490 183.670 3606.94 3708.79 639.07 S 3040.03 W 5968149.49 N 558571.50 E 1.180 639.07
8331.54 90.430 182.910 3606.51 3708.36 693.02 S 3043.13 W 5968095.52 N 558568.84 E 1.411 693.02
8372.00 90.370 182.030 3606,22 3708.07 733.44 S 3044.88 W 5968055.09 N 558567.43 E 2.180 733.44
8425.72 90.490 181.840 3605.82 3707.67 787.13 S 3046.69W 5968001.39 N 558566.05 E 0.418 787.13
8463.42 90.370 181.380 3605.54 3707.39 824.81 S 3047.75 W 5967963.70 N 558565.30 E 1.261 824.81
8521.67 90.370 181.870 3605.16 3707.01 883.04 S 3049.40 W 5967905.46 N 558564.13 E 0.841 883.04
8561.07 91.540 182.070 3604.51 3706.36 922.41 S 3050.76 W 5967866.08 N 558563.1 0 E 3.013 922.41
8616.21 91.660 182.140 3602.97 3704.82 977.49 S 3052.78 W 5967810.98 N 558561.53 E 0.252 977.49
8655.21 91 ;230 182.100 3601.98 3703.83 1016.45 S 3054;22 W 5967772.01 N 558560.41 E 1.107 1016.45
8709.56 90.620 181.610 3601.11 3702.96 1070.76 S 3055.98 W 5967717.68 N 558559.09 E 1 .440 1070.76
--- --0'___'- __n______-------
--o-uo-o-
7 November, 2001 - 13:25
Page 3 of 6
DrlllOllest 2.00.09.003
Sperry-Sun Drilling Services .
Survey Report for 1C-102L 1
Your Ref: AP/500292303760
Job No. AKMM111441 Surveyed: 15 September I 2001
North Slope, Alaska
Kuparuk River Unit . Kuparuk 1 C
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. . Azlm. Depth Depth Northing! . Eastlngs Northlngs Eastlngs Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft)
8752.20 90.180 181.450 3600.81 3702.66 1113.39 S 3057.12 W 5967675.05 N 558558.30 E 1.098 1113.39
8805.88 90.000 180.040 3600.72 3702.57 1167.06 S 3057.82 W 5967621.38 N 558558.05 E 2.648 1167.06
8847.68 90.120 180.910 3600.68 3702.53 1208.86 S 3058.16 W 5967579.58 N 558558.04 E 2.101 1208.86 -"""
8900.40 89.880 180.880 3600.68 3702.53 1261.57 S 3058.99 W 5967526.86 N 558557.65 E 0.459 1261.57 -'
8941.62 90.800 180.750' 3600.43 3702.28 1302.79 S 3059.57 W 5967485.64 N 558557.40 E 2.254 1302.79
8992.10 91.540 181.330 3599.40 3701.25 1353.25 S 3060.49 W 5967435.17 N 558556.90 E 1.862 1353.25
9039.08 90.180 181 .190 3598.70 3700.55 1400.21 S 3061.52 W 5967388.20 N 558556.26 E 2.910 1400.21
9087.17 90.680 180.330 3598.34 3700.19 1448,29 S 3062.16 W 5967340.12 N 558556.01 E 2.069 1448.29
9134.74 93.630 119.840' 3596.55 3698.40 1495.82 S 3062.23 W 5967292.59 N 558556.33 E 6.286 1495.82
9183.70 92.650 179.480 3593.87 3695.72 1544,71 S 3061.94 W 5967243.71 N 558557.02 E 2.132 1544.71
9234.71 90.620 176.820 3592.41 3694.26 1595.66 S 3060.30 W 5967192.77 N 558559.09 E 6.558 1595.66
9278.55 90.680 177.790 3591.91 3693.76 1639.45 S 3058.23 W 5967149.00 N 558561.51 E 2.217 1639.45
9326.02 90.430 177.220 3591.46 3693.31 1686.87 S 3056.17 W 5967101.59 N 558563.96 E 1.311 1686.87
9373.96 90.490 176.770 3591.07' 3692.92 1734.75 S 3053.65 W 5967053.74 N 558566.87 E 0.947 1734.75
9420.93 90.250 175.450 3590.77 3692.62 1781.61 S 3050.47 W 5967006.91 N 558570.44 E 2.856 1781.61
9467.84 90.250 175.040 3590.56 3692.41 1828.35 S 3046.58 W 5966960.19 N 558574.71 E 0.874 1828.35
9515.87 90.310 174.410 3590.33 3692.18 1876.18 S 3042.16 W 5966912.41 N 558579.52 E 1.318 1876.18
9562.96 90.800 174.720 3589.87 3691.72 1923.068 3037.70W 5966865.57 N 558584.37 E 1.231 1923.06
9605.90 90.250 174.180 3589.48 3691.33 1965.79 S 3033.55 W 5966822.87 N 558588.87 E 1.795 1965.79
9658.26 90.000 173.380 3589.36 3691.21 2017.84 S 3027.88 W 5966770.87 N 558594.97 E 1.601 2017.84
.-,
..,
9700.75 88.770 174.980 3589.82 3691.67 2060.11 S 3023.57 W 5966728.64 N 558599.63 E 4.749 2060.11
9753.33 89.260 174.370 3590.72 3692.57 2112.46 S 3018.69 W 5966676.33 N 558604.93 E 1.488 2112.46
9798.11 87.970 176.900 3591.81 3693.66 2157.09 S 3015,28 W 5966631.73 N 558608.71 E 6.340 2157.09
9847.55 88.210 178.790 3593.45 3695.30 2206.46 S 3013.43 W 5966582.37 N 558610.97 E 3.851 2206.46
9889.08 89.570 179.420 3594.26 3696.11 2247.98 S 3012.78 W 5966540.86 N 558611.96 E 3.609 2247.98
9941.44 91.850 179.470 3593.61 3695.46 2300.33 S 3Ò12.27 W 5966488.52 N 558612.90 E 4.356 2300.33
9983.12 91.970 179.630 3592.22 3694.07 2341.98 S 3011.94W 5966446.87 N 558613.57 E 0.480 2341.98
10032.00 91.230 178.080 3590.86 3692.71 2390.83 S 3010.97 W 5966398.03 N 558614.94 E 3.513 2390.83
10076.06 90.800 178.410 3590.08 3691.93 2434.87S 3009.62 W 5966354.01 N 558616.65 E 1.230 2434.87
10131.27 91.110 176.890 3589.15 3691.00 2490.02 S 3007.35 W 5966298.87 N 558619.37 E 2.809 2490.02
u- _d __n
-----
7 November, 2001 - 13:25
Page 4 of 6
DrIllQuesI2.00.09.003
.
. Sperry-Sun Drilling Services
Survey Report for 1C-102L 1
Your Ref: API500292303760
Job No. AKMM11144, Surveyed: 15 September, 2001
.
.
North Slope, Alaska
Kuparuk River Unit Kuparuk 1 C
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft)
.
10172.43 91.350 177.520 3588.27 3690.12 2531.128 3005.35 W 5966257.79 N 558621.71 E 1.638 2531.12
10225.98 91.540 176.630 3586.92 3688.77 2584.58 8 3002.62 W 5966204.35 N 558624.88 E 1.699 2584.58
; 10266.48 91.350 175.270 3585.90 3687.75 2624.97 8 2999.76 W 5966163.99 N 558628.08 E 3.390 2624.97 ~.
"--, 1 0320.27 91.600 175.250 3584.52 3686.37 2678.56 8 2995.31 W 5966110.44 N 558632.96 E 0.466 2678.56
10360.51 91.720 175.330 3583.35 3685.20 2718.65 8 2992.01 W 5966070.38 N 558636.59 E 0.358 2718.65 ~
10413.98 89.200 174.610 3582.92 3684.77 2771.908 2987.32 W 5966017.17 N 558641.72 E 4.901 2771.90
10445.37 88.770 174.580 3583.48 3685.33 2803.158 2984.37 W 5965985.94 N 558644.93 E 1.373 2803.15
10478.1 7 88.830 174.260 3584.16 3686.01 2835.79 8 2981.18 W 5965953.33 N 558648.38 E 0.992 2835.79
10509.58 88.950 174.380 3584.77 3686.62 2867.04 8 2978.07 W 5965922.11 N 558651.75 E 0.540 2867.04
10521.44 88.950 174.370 3584.99 3686.84 2878.84 8 2976.91 W 5965910.32 N 558653.01 E 0.084 2878.84
10600.00 88.950 174.370 3586.43 3688.28 2957.00 8 2969.20 W 5965832.22 N 558661.36 E 0.000 2957.00 Projected Survey
All data is in Feet (U8) unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to RKB = 101.85' (M8L). Northings and Eastings are relative to 1420' FNL & 600' FWL.
Magnetic Declination at 8urface is 26.144° (24-Aug-01)
The Dogleg Severity is in Degrees per 100 feet (U8).
Vertical 8ection is from 1420' FNL& 600' FWL and calculated along an Azimuth of 180.000° (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 10600.0Ott.,
The Bottom Hole Displacement is 4190.47ft, in the Direction of 225.118° (True).
~
-. -- -------
.---.----
7 November, 2001 - 13:25
Page 5 of 6
Or/llOuest 2.00.09.003
.
..
Kuparuk River Unit
Comments
Measured
Depth
(ft)
\.......-
5854.56
.5941..00
. 10600.00
Sperry-Sun Drilling Services
Survey Report for 1 C-1 02L 1
Your Ref: API 500292303760
Job No. AKMM11144, Surveyed: 15 September, 2001
Station Coordinates.
TVD Northings Eastlngs
. (ft) (ft) (ft)
3648.15
3679.63
3688.28
1721.55 N
1653.48 N
2957.00 S
Survey tool program for 1C-l02L 1
From
Measured Vertical
Depth Depth
(ft) (ft)
0.00
..- u----
7 November, 2001 - 13:25
0.00
To
Measured Vertical
Depth Depth
(ft) (ft)
10600.00
3688.28
--.--0 _-_0__-_0
Comment
2824.81 W
2867.79 W
2969.20 W
Tie on Point
Window Point
Projected Survey
Survey Tool Description
MWD Magnetic (1 C-1 02)
Page 6 of 6
.
North Slope, Alaska
Kuparuk 1C
~)
l
------.---
DrlllQuest 2.00.09.003
~ ~ ~
~~PHILLIPS '}
IUj
....,.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
8/17/2001
8/18/2001
8/19/2001
8/20/2001
Date
t
('
PHilliPS ALASKA INC.
Operations Summary Report
1 C-1 02
1C-102
ROT - DRILLING
Sub
From - To Hours Code Code Phase
07:00 - 09:30
09:30 -11:00
11:00 -12:00
12:00 - 14:00
14:00 - 16:00
16:00 - 21 :00
21 :00 - 22:30
22:30 - 23:00
23:00 - 00:00
00:00 - 02:00
02:00 - 02:30
02:30 - 11 :00
11 :00 - 12:00
12:00 - 13:00
13:00 - 17:00
17:00 - 22:00
22:00 - 23:30
23:30 - 00:00
00:00 - 03:30
03:30 - 04:30
04:30 - 06:00
06:00 - 06:30
06:30 - 08:30
08:30 - 09:00
09:00 - 09:30
09:30 - 10:00
10:00 - 13:30
13:30 - 14:00
14:00 - 00:00
00:00 - 08:30
2.50 MOVE
1.50 MOVE
1.00 MOVE
2.00 MOVE
MOVE MOBMIR
OTHR MOBMIR
MOVE MOBMIR
MOVE MOBMIR
2.00 WELCTL NUND SURFAC
5.00 WELCTL NUND SURFAC
1.50 RIGMNT RURD SURFAC
0.50 RIGMNT RSRV SURFAC
1.00 DRILL OTHR SURFAC
2.00 DRILL
0.50 DRILL
8.50 DRILL
1.00 DRILL
1.00 DRILL
4.00 DRILL
5.00 DRILL
1.50 DRILL
0.50 DRILL
3.50 DRILL
1.00 DRILL
1.50 DRILL
OTHR SURFAC
OTHR SURFAC
PULD SURFAC
SFTY SURFAC
OTHR SURFAC
OTHR SURFAC
PULD SURFAC
DRLG SURFAC
DRLG SURFAC
DRLG SURFAC
OTHR SURFAC
SURV SURFAC
0.50 DRILL TRIP
2.00 DRILL SURV
0.50 DRILL SURV
0.50 DRILL SURV
0.50 DRILL CIRC
3.50 RIGMNT RGRP
SURFAC
SURFAC
SURFAC
SURFAC
SURFAC
SURFAC
0.50 RIGMNT RSRV SURFAC
10.00 DRILL DRLG SURFAC
8.50 DRILL
DRLG SURFAC
Page 1 of 15
Start: 8/16/2001
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
Description of Operations
Raise Cellar box, prep rig and move fl 1 C-1
19 to 1C-102 (270' away fl CPM)
Load casing on truck and move matting boar
ds for move to 1C-102
Set drill module over hole.
Skid floor7" towards pipe shed. Mate utility
module to drill module. Set CPM.
NU diverter line and knife valve, mix spud m
u d.
PU 10' riser & NU 13 5/8" 5m stack. Raise ri
g 8" by jacking off Lampson crawler to set B
OP stack on riser. Welder cut wall out to fit
choke and kill lines. Welder shorten length
of slip joint on flow line riser.
Slip and cut 93' of drilling line.
Service rig and top drive.
LD 3 1/2" jars & 2 joints of 3 1/2" HWDP. Lo
ad 4" Weatherford rental drill pipe in pipe s
hed and prep to pick up.
Prepare weatherford 4" HT38 drill pipe, stra
p and rabbit in pipe shed.
Change top drive saver sub to 4 1/2" IF box
x 4" HT 38 pin.
PJSM. PU and stand back in derrick 4" OP,
4" HWDP, and drill collars.
Pre spud meeting wI team members.
Function test diverter system. Witness of f
unction test waived by AOGCC inspector Jef
f Jones. Dry test casing hanger with landing
joint. OK. Lay down hanger and landing join
t.
MU wear bushing, run in & set in head. Trou
ble working thru BOP stack @ 13+ ft.
MU BHA. Orient and program tools.
Break circulation, clean ice out of conducto
r from 85' to 158'.
Drill 9 7/8" hole f/ 158' to 181'.
Drill 9 7/8" hole fl 181' to 257' (76') ADT
25 hrs AS AT .25 hrs
Flowline plugged off with gravel.
Attempt survey. Tool failure. Circ hole clea
n, blow down top drive.
Trip out of hole to check MWD tools.
Download MWD, LD pulsar.
PU MWD, orient and program tools.
Trip in hole
Wash to 257'. 40' fill.
Change out and rebuild DISCFLOW pump to
move cuttings to CPM.
Service rig and top drive.
Directional drill 9 7/8" hole f/ 257' t01190'.(
933') ART 2 hrs. AST 6.4 hrs
Directional drill 97/8" hole f/ 1190' to 1795
Printed: 11/30/2001 11:17:54AM
~ ~ ~
~'PHILLlPS~
I{Ø
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
8/20/2001
8/21/2001
8/22/2001
8/23/2001
8/24/2001
{
'(
PHilliPS ALASKA INC.
Operations Summary Report
Page 2 of 15
1 C-1 02
1C-102
ROT - DRILLING
Start: 8/16/2001
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
Sub
From - To Hours Code Code Phase
00:00 - 08:30
08:30 - 09:30
09:30 - 12:00
12:00 - 12:30
12:30 - 00:00
00:00 - 04:30
04:30 - 05:00
05:00 - 08:30
08:30 - 12:00
12:00 - 12:30
12:30 - 13:00
13:00 - 16:00
16:00 - 16:30
16:30 - 00:00
00:00 - 12:00
12:00 - 12:30
12:30 - 00:00
00:00 - 01 :00
01:00 - 01:30
01 :30 - 06:30
06:30 - 07:00
07:00 - 09:00
09:00 - 14:30
14:30 - 19:00
19:00 - 19:30
19:30 - 20:30
20:30 - 22:30
22:30 - 00:00
00:00 - 04:00
Description of Operations
8.50 DRILL
1.00 DRILL
DRLG SURFAC
CIRC SURFAC
'(605') ART.3 hrs AST 6.1 hrs
Stand back 1 stand of DP. Circ hole. Confir
m with town that directional profile will be
OK.
Directional drill 9 7/8" hole fI 1795' to 1948
, (153') ART = 0 hrs AST =1.3 hrs
Service rig and top drive.
Directional drill 9 7/8" hole from 1948' 10 33
68' (1420') ART = 5.4 hrs. AST = .7 hrs
TVD 2360'
Directional drill 9 7/8" hole f/ 3368' to 3841
, (473') ART = 2.6 hrs
Circulate sweep and clean hole prior to trip.
2.50 DRILL
DRLG SURFAC
0.50 RIGMNT RSRV SURFAC
11.50 DRILL DRLG SURFAC
4.50 DRILL
DRLG SURFAC
0.50 DRILL
CIRC SURFAC
3.50 DRILL TRIP SURFAC M 0 nit 0 r well. P u m p dry job. B low do W n top d
'rive. POOH. Monitor @ HWDP. Continue POO
H. Tight spot @ 308'. Work through tight sp
ot. Monitor well @ DC's. Continue POOH. Ch
ange out bit.
SURFAC D 0 w n loa d and pro g ram M W D too Is.
SURFAC R I H to 1 s t H W D P. T est M W D .
SURFAC S e r v ice rig and top d r i v e .
SURFAC R I H wi bit # 2.
SURFAC Pre c aut ion a r y rea m 1 9 0' to bot tom.
SURFAC>:QDirectional drill 97/8" hole f/ 3841' to 4598
,...Þ (757') ART = 2.4 hrs AST = 2.4 hrs
12.00 DRILL DRLG SURFAC D ire c t ion a I d rill 9 7/8" h 0 I e f / 4598' to 51 68
'(570') ART = 1.3 hrs AST = 7.5 hrs.
0.50 RIGMNT RSRV SURFAC S e r vi c e rig and top d r i v e
11.50 DRILL DRLG SURFAC D ire c t ion a I d rill 9 7/8" h 0 I e f /
'(757') ART = 4.2 hrs AST
1.00 DRILL DRLG SURFAC D ire c t ion a I d rill 9 7/8" h 0 Ie fI
, (30') ART =.5 hrs.
0.50 DRILL CIRC SURFAC C i r cui ate h 0 Ie.
5.00 DRILL DRLG SURFAC D ire c t ion a I d rill 9 7/8" h 0 I e f / 5 9 5 5' to 609 1
'(36') ART = .6hrs. AST =2.8 hrs.
0.50 DRILL SURV SURFAC At t e m p t to sur v e y w / M W D. Fa ¡Ie d .
2.00 DRILL CIRC SURFAC Mix and p u m phi - den sit Y s wee p p r ¡or tot rip
fI MWD failure.
5.50 DRILL TRIP SURFAC 'M 0 nit 0 r well, p u m p dry job, b low do w n 10 P d
rive, POOH for MWD. Tight spot @ 5535',25
k over. Work through, OK. Tight spot @ 721'
, 25 k over. Work through, OK.
4.50 DRILL PULD SURFAC Do w n loa d M W D. C h a n g e 0 u t too Is, pro g ram a
nd orient same.
'Run in hole to 1190'.
Check MWD. Pulsar failed to operate.
P'OOH for pulsar problem.
Change out pulsar.
RIH w/ 9 7/8" bit. Check shot w/ MWD @ 302
, (OK), 1184' (OK), 2230' (OK). Continue RI
H to 4225'. Lay down and change out joint 0
f 4" D P.
3.50 DRILL SURV
0.50 DRILL TRIP
0.50 RIGMNT RSRV
3.00 DRILL TRIP
0.50 DRILL REAM
7.50 DRILL DRLG
5168' to 5925
=3.7 hrs.
5925' to 5955
0.50 DRILL
1.00 DRILL
2.00 DRILL
1.50 DRILL
4.00 DRILL
TRIP SURFAC
SURV SURFAC
TRIP SURFAC
PULD SURFAC
TRIP SURFAC
Printed: 11/30/2001 11 :17:54 AM
Legal Well Name: 1 C-1 02
Common Well Name: 1 C-1 02
Event Name: ROT - DRILLING
Contractor Name:
Rig Name:
Date From - To Hours Code Sub Phase
Code
8/24/2001 04:00 - 05:00 1.00 DRILL
05:00 - 07:00 2.00 DRILL
07:00 - 10:00 3.00 DRILL
10:00 - 10:30 0.50 DRILL
CIRC SURFAC Circ and condition mud and hole. Check shot
W/ MWD @ 4183' (Weak signal, suspect wil
I have future problems).
TRIP SURFAC Con ti n u e t rip in h 0 let 0 551 9' .
CIRC SURFAC C i r cui ate and p u m phi - den sit Y s wee p. T est
MWD, not very strong of signal.
TRIP SURFAC Con tin u e t rip i n h 0 I e f / 55 1 9' to 596 1 '. Pre c
autionary wash f/ 5961' to 6091' (130'). No
Fi II.
DRLG SURFAC D rill f / 609 l' to 6 1 00' (9') ART = . 25 h r s TV
D = approx 3732'.
CrRC SURFAC C i r cui ate and con d it ion h 0 I e p r i 0 r tot rip 0 u t
4 f/ MWD tools.
CIRC SURFAC M 0 nit 0 r well, p u m p dry job, b low do w n Top d
r i ve.
POOH to HWDP @ 1100'.
Pump up survey. Blow down Top Drive.
Continue POOH.
Download Baker tools. Lay down MWD and m
0 tor.
RIRD SURFAC Rig do w n B a k e r Hug h e sin t e q e qui p men t .
RIRD SURFAC Rig up Sperry Sun equipment.
RIRD SURFAC Rig upS parr y Sun sur f a c a a qui pm ant f / M W
D-LWD-PWD servicas.
PULD SURFAC PUB H A, 0 ria n tan d sur f a cat a st.
TRIP SURFAC R I H w / bit # 3. Too k wa i g h t @ 1 8 02, 2053, 2
057,3410,3653,4127. Continue RIH to 580
0' .
SURV SURFAC M a a sur e man t aft a r D rill i n g (M A D pas s) f / 5 8
00' to 6100'. Tia in log for Sparry Sun. No
ta : Within 1'.
DRLG SURFAC D ire c ti 0 n a I d rill 9 7/8" h 0 I a f/ 6 1 00' to 652 8
, (428') ART 1.4 hrs. AST 5.9 hrs. TVD
3800'. Gaologist picks: Top of wast sak D
@ 6130' MD = 3741'TVD Top of west sak C
@ 6270' MD = 3774'TVD Top of west sak B
@ 6396' MD = 3796' TVD
CIRC SURFAC C i r cui a t a @ T D 0 f sur f a c a h 0 I e (652 8 I ) .
TRIP SURFAC M 0 nit 0 r wall, p u m p dry job, P 00 H, m 0 nit 0 r
@ BHA.
PULD SURFAC L / D M W D & B H A. C I a a r rig f I 0 0 r .
PULD SURFAC PUB H A # 6 w / h 0 I a 0 pen e r, s tab ¡Ii z e r san d
X-O.
TRIP SURFAC T rip in h 0 Ie w / 9 7/8" h 0 I e 0 pen e r. Was h an
d ream through dog legs @ 1120',2159', an
d 4433'. No problems. Continue trip in to 52
35' .
1.50 DRILL REAM SURFAC Pre c aut ion a r y was h and rea m f / 6235' to 652
8' .
2.50 DRILL CIRC SURFAC Circulate and condition mud and hole f/ casi
ng. Pump hi vis-dansity sweep.
0.50 DRILL OBSV SURFAC M 0 nit 0 r wall, p u m p dry job, b low do w n top d
r i v e.
t'
...... ~
(PH I LÜPS Ì
I~
10:30 - 11 :00 0.50 DRILL
11 :00 - 12:00 1.00 DRILL
12:00 - 12:30 0.50 DRILL
12:30 - 15:30 3.00 DRILL
15:30 - 16:00 0.50 DRILL
16:00 - 17:00 1.00 DRILL
17:00 - 18:30 1.50 DRILL
18:30 - 21 :00 2.50 DRILL
21 :00 - 00:00 3.00 DRILL
8/25/2001 00:00 - 05:30 5.50 DRILL
05:30 - 07:00 1.50 DRILL
07:00 - 11 :00 4.00 DRILL
11 :00 - 12:30 1.50 DRILL
12:30 - 00:00 11.50 DRILL
8/26/2001 00:00 - 01 :30 1.50 DRILL
01 :30 - 06:00 4.50 DRILL
06:00 - 07:30 1.50 DRILL
07:30 - 08:30 1.00 DRILL
08:30 - 11 :30 3.00 DRILL
11 :30 - 13:00
13:00 - 15:30
15:30 - 16:00
í
PHilliPS ALASKA INC.
Operations Summary Report
Page 3 of 15
Start:
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
8/16/2001
Description of Operations
TRIP SURFAC
SURV SURFAC
TRIP SURFAC
SURV SURFAC
Printed: 11/30/2001 11: 17:54 AM
~ ~
,- -,
~ PHilLIPS ~
1U:j
"V'
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
8/26/2001
8/27/2001
8/28/2001
8/29/2001
Date
l
f
(
PHilliPS ALASKA INC.
Operations Summary Report
1 C-1 02
1C-102
ROT - DRILLING
Page 4 of 15
Start: 8/16/2001
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
Sub
From - To Hours Code Code Phase,-
TRIP SURFACJþOOH wI 9 7/8" hole opener.
PULD SURFAC Lay do w n B H A .
OTHR SURFAC Pull w ear bus h i n g .
RURD SURFAC C h a n g e s a v e r sub 0 n top d r i vet 0 4 1/2 II IFf
~r fillup tool, MU fillup tool, RU casing crew
16:00 -19:30
19:30 - 20:30
20:30 - 21 :30
21 :30 - 23:30
23:30 - 00:00
00:00 - 11 :00
11 :00 - 16:30
16:30 - 20:30
20:30 - 21 :30
21 :30 - 00:00
00:00 - 01 :00
01 :00 - 03:30
03:30 - 07:00
07:00 - 10:00
10:00 - 11 :00
11 :00 - 12:00
12:00 - 12:30
12:30 - 13:00
13:00 - 16:00
16:00 - 21:00
21 :00 - 00:00
00:00 - 01 :00
01 :00 - 02:00
02:00 - 03:30
03:30 - 06:00
06:00 - 06:30
06:30 - 07:00
3.50 DRILL
1.00 DRILL
1.00 DRILL
2.00 CASE
0.50 CASE
11.00 CASE
Description of Operations
SFTY SURFAC
Hold pre job meeting wI rig team members p
~ior to running 7 5/8" surface casing.
Pre job safety meeting, run 7 5/8" casing to
6518' .
Circulate and condition mud and hole while
reciprocating casing. Circulated total of 125
2, bbls (12400 strokes). PU weight = 245 k
SO weight = 120 k
PJSM, DowelllSchlumber test lines to 3500
psi. Cement per well plan. Bump plug @ 29
96 strokes, pressure up to 2500 psi. Check f
loats. OK.
Flush out stack. RID cement equipment LI
D landing joint. Install flange on diverter sp
001.
PU Test joint and running tool. Set packoff.
Change bottom pipe rams f/ 3 1/2" to variabl
e rams 2 7/8" X 5".
Test pack off to 5000 psi.
Tighten rams doors. Remove knife valve & fl
ange, 4" cement valves, Install 16", 5M Blin
d flange.
Rig up test equipment & test BOPE complete
to 250 psi & 5000 psi. Annular to 250 psi &
3500 psi. Perform accumulator test. Witnes
sing of test waived by AOGCC rep. Chuck Sc
h eve.
Install wear bushing. Opening would not line
up with wing valve. Pull wear bushing for m
odification.
Cut Drilling line 86'.
Install wear bushing after modification.
Service Rig & Top Drive
Change elevators, rig up floor for tripping
PIU BHA, Orient & program tools.
Shallow test MWD equipment. RIH wI excess
DP & LID same.
RIH wI Drilling Assy. SLM.
RIH to 6432' MD
Circ. bottoms up
RIU and run casing test to 3000 psi for 30 m
ins., held ok
Drill out float equipment and cement to shoe
@ 6518', clean out rat hole to 6528'
Drill new formation F/6528' to 6548' ART hr
s=.1 ASThrs=.2
Circ. bottoms up
RUNC SURFAC
5.50 CEMENl CIRC SURFAC
4.00 CEMENl PUMP SURFAC
1.00 CEMEN OTHR SURFAC
2.50 WELCTL NUND PROD
1.00 WELCTL NUND PROD
2.50 WELCTL NUND PROD
3.50 WELCTL BOPE PROD
3.00 WELCTL OTHR PROD
1.00 RIGMNT RSRV
1.00 WELCTL OTHR
0.50 RIGMNT RSRV
0.50 DRILL RIRD
3.00 DRILL TRIP
5.00 DRILL TRIP
3.00 DRILL
1.00 DRILL
1.00 DRILL
1.50 DRILL
PROD
PROD
PROD
PROD
PROD
PROD
TRIP PROD
TRIP PROD
CIRC PROD
DEOT PROD
0.50 DRILL
2.50 CEMENl DSHO PROD
0.50 DRILL
CIRC
DRLG PROD
PROD
Printed: 11/30/2001 11:17:54 AM
... ....... ~
<,,"pHiLLïps f
I[Ð
8/30/2001
8/31/2001
9/1/2001
9/2/2001
{'
(
PHilliPS ALASKA INC.
Operations Summary Report
00:00 - 00:30 0.50 DRILL DRLG PROD
00:30 - 01 :00 0.50 DRILL RIRD PROD
01 :00 - 20:30 19.50 DRILL DRLG PROD
20:30 - 21 :30 1.00 DRILL CIRC PROD
21 :30 - 22:30 1.00 DRILL WIPR PROD
22:30 - 23:00 0.50 RIGMNT RSRV PROD
23:00 - 00:00 1.00 DRILL WIPR PROD
00:00 - 00:30 0.50 DRILL WIPR PROD
00:30 - 23:30 23.00 DRILL DRLG PROD
23:30 - 00:00 0.50 DRILL CIRC PROD
00:00 - 01 :00 1.00 DRILL CIRC PROD
01 :00 - 01 :30 0.50 DRILL SFTY PROD
01 :30 - 10:00 8.50 DRILL TRIP PROD
10:00 - 11 :00 1.00 DRILL PULD PROD
11 :00 - 12:00 1.00 DRILL PULD PROD
12:00 - 16:00 4.00 DRILL TRIP PROD
16:00 - 16:30 0.50 RIGMNT RSRV PROD
16:30 - 00:00 7.50 DRILL REAM PROD
00:00 - 08:30
8.50 DRILL REAM PROD
Legal Well Name: 1 C-1 02
Common Well Name: 1 C-1 02
Event Name: ROT - DRILLING
Contractor Name:
Rig Name:
Date From - To Hours Code Sub Phase
Code
8/29/2001 07:00 - 10:30 3.50 DRILL OTHR PROD
10:30 - 11 :30 1.00 DRILL CIRC PROD
11 :30 - 12:00 0.50 DRILL OTHR PROD
12:00 - 13:00 1.00 DRILL FIT PROD
13:00 - 23:00 10.00 DRILL OTHR PROD
23:00 - 00:00 1.00 DRILL DRLG PROD
08:30 - 15:30
7.00 DRILL CIRC PROD
15:30 - 18:30
3.00 DRILL TRIP PROD
Page 5 of 15
Start:
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
8/16/2001
Description of Operations
Clean mud pits and flush surface equipment
Circ. Lo vis/High vis sweep, displace hole w
ith 9.1 ppg. Baradrill;N mud
Continue to clean and flush surface mud cir
culating system.
Perform FIT test to 12 ppg. @ 600 psi
Continue to clean and flush surface mud cir
culating system
Drill F/6548' to 6601' MD, 3802' TVD ART =
.45 hrs. AST =.0 Circ. & survey = .55 hrs
Drill from 6601' to 6651', shakers blinding 0
ff, losing mud
Change shaker screens
Drill from 6651' to 8495' MD, 3767' TVD AS
T = 2.25 hrs. ART = 10.5 hrs.
Circ., pump high vis low vis sweep, circ bott
oms up
Wiper trip to the shoe (6518'), had tight spo
tat 7700', wiped once and it was gone.
Service top drive
TIH, currtently at 7900', hole in good shape
TIH to 8406', wash last stand to bottom 849
5' 0
Drill from 8495' to 10570' MD, 37653' TVD
AST = 3.75 hrs. ART = 10.25 hrs.
Circ. and condo hole, pump high vis sweep
Circ and cond hole
Check for flow, pre-job safety meeting, pum
p dry job
POOH, no tight spots, check for flow at sho
e, continue out of hole.
Down load MWD, L/D MWD and mud motor
P/U 6 3/4" hole opener, reamer and stabilize
rs
TIH to shoe, 6518'
Service top drive
Wash and Ream each stand down and up and
washing down from 6518' to 8533', have se
en no torque or drag. RPM 90 Pump 300 G
PM
Wash and Ream to 10570, reaming each con
nection once, had one tight spot at 9332', r
earned thru once and didn't see again.
Circ and cond hole, pump sweep and circ bo
t tom sup, p u m p 3 0 b b Is. M - I pus h pill , folio
wed with 600 bbls. 8.9 kcl brine, followed b
y 290 bbls HeC high vis brine. Clean fluid c
oming in returns.
POOH using trip tank to 7 5/8" casing shoe,
losses show hole taking 10 bbls. per hr, plu
s the pipe displacement, no tight spots or e
Printed: 11/30/2001 11:17:54 AM
~ ~ ~
~~PHILLlPS)
IW)
....,.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
9/2/2001
9/3/2001
9/4/2001
9/5/2001
Date
f
f
"
PHilliPS ALASKA INC.
Operations Summary Report
1 C-1 02
1 C-1 02
ROT - DRILLING
Sub
From - To Hours Code Code Phase
15:30 -18:30
18:30 - 19:30
19:30 - 23:30
23:30 - 00:00
00:00 - 01 :30
01 :30 - 02:00
02:00 - 05:00
05:00 - 08:00
08:00 - 09:00
09:00 - 10:30
10:30 - 11 :00
11 :00 - 11 :30
11 :30 - 15:30
15:30 - 23:30
23:30 - 00:00
00:00 - 05:00
05:00 - 05:30
05:30 - 06:00
06:00 - 06:30
06:30 - 17:30
17:30 - 18:30
18:30 - 00:00
00:00 - 01 :00
01 :00 - 02:00
02:00 - 02:30
02:30 - 10:30
10:30 - 11 :30
11 :30 - 13:00
13:00 - 14:30
3.00 DRILL
1.00 DRILL
TRIP PROD
CIRC PROD
4.00 DRILL
TRIP
PROD
0.50 RIGMNT RURD PROD
1.50 RIGMNT RURD PROD
0.50 RIGMNT RSRV PROD
3.00 CMPL TN PULD CMPL TN
3.00 CMPLTN TRIP
CMPLTN
1.00 CMPLTN CIRC CMPLTN
1.50 WAlTON EalP CMPLTN
0.50 CMPL TN SFTY CMPL TN
0.50 CMPL TN RURD CMPL TN
4.00 CMPLTN CIRC CMPLTN
8.00 CMPLTN AWSH CMPLTN
0.50 CMPLTN TRIP
5.00 CMPL TN TRIP
CMPL TN
CMPL TN
0.50 CMPL TN RURD CMPL TN
0.50 RIGMNT RSRV CMPL TN
0.50 CMPL TN SFTY CMPL TN
11.00 CMPL TN SCAN CMPL TN
1.00 CMPL TN RURD CMPL TN
5.50 CMPL TN TRIP
CMPL TN
1.00 CMPL TN TRIP CMPL TN
1.00 CMPLTN SOHO CMPLTN
0.50 CMPL TN SFTY CMPL TN
8.00 CMPL TN SCAN CMPL TN
1.00 CMPL TN SEaT CMPL TN
1.50 CMPL TN PCKR CMPL TN
1.50 CMPLTN CIRC CMPLTN
Page 6 of 15
Start: 8/16/2001
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
Description of Operations
xcess drag coming out.
Circ. high vis brine out of hole, continue to
circ. until clean brine is at surface.
POOH, LID stabilizers, reamers and hole op
ener
Slip and Cut drill line
Finish slip and cutting drill line
Service top drive
PIU BHA, scrapers, 18 - 4 3/4" DC's, 30 - 4"
HWDP and RIH
TIH with 4" drill pipe to 6512' - strap going
in h 0 Ie
Circ. clean brine
Continue to circ, while waiting on caustic w
ash, trucks were stuck behind rig move comi
ng from BP side
Pre-job safety meeting
R/U to do caustic wash on DP and casing
Pump 75 bbls caustic wash, displace with 8.
9 clean brine. Diverted caustic wash to vac.
truck and circ. hole clean.
Pump 500 gals 15% HCL acid to pickle Drill
string. Displace down drill string at 1/2 BPM
to bit. Reverse circ. acid back to surface,
putting acid in open top tank, acid come bac
k clean looking. Continue reverse circ. brin
e until it cleaned up. Displace casing with H
EC viscosified. brine. Check for flow.
TOOH strapping pipe
POOH strapping and drifting drill string, LID
bit and scrapers
R/U to run 4" liner
Rig service
Hold pre-job safety meeting and running pro
cedure with rig employees and service comp
any personal
Run 4" liner and screens to 4500'
R/U to run Baker cup assembly and 2 7/8" tu
bing
RIH inside 4" liner with 2 7/8" tubing and Ba
ker cup assembly to 3800' at report time.
Finish RIH with 2 7/8" tubing, total 148 jts.
Space out tubing and install liner hanger pa
cker
Hold pre-job safety meeting
RIH W/4" liner and screens, set at 10551' M
D
Hold pre-job meeting, R/U and test lines to
4000 psi
Set liner hanger packer at 6042.45', staging
pressure to 3500 psi. Test annulus to 1000
psi, release from packer.
Blow ball seat and circ. 500 bbls filtered 8.
Printed: 11/30/2001 11:17:54AM
{
~ ....... ~
~'P¡¡¡LùPS'~
, j
~I
....,.
(
Page 7 of 15
PHilliPS ALASKA INC.
Operations Summary Report
Legal Well Name: 1 C-1 02
Common Well Name: 1 C-1 02
Event Name: ROT - DRILLING
Contractor Name:
Rig Name:
Date From - To Hours Code Sub Phase
Code
9/5/2001 13:00 - 14:30 1.50 CMPLTN CIRC CMPL TN
14:30 - 16:30 2.00 CMPL TN CIRC CMPL TN
16:30 - 19:00 2.50 CMPL TN AWSH CMPL TN
19:00 - 19:30 0.50 CMPLTN CIRC CMPL TN
19:30 - 21 :00 1.50 CMPLTN AWSH CMPL TN
21 :00 - 21 :30 0.50 CMPL TN CIRC CMPL TN
21 :30 - 22:30 1.00 CMPLTN AWSH CMPL TN
22:30 - 23:30 1.00 CMPL TN CIRC CMPL TN
23:30 - 00:00 0.50 CMPL TN AWSH CMPL TN
9/6/2001 00:00 - 03:00 3.00 CMPL TN TRIP CMPL TN
03:00 - 06:00 3.00 CMPLTN AWSH CMPL TN
06:00 - 08:30 2.50 CMPL TN CIRC CMPL TN
08:30 - 11 :30 3.00 CMPL TN TRIP CMPL TN
11 :30 - 12:00 0.50 CMPL TN DEQT CMPL TN
12:00 - 13:30 1.50 CMPLTN TRIP CMPL TN
13:30 - 19:30 6.00 CMPL TN PULD CMPL TN
19:30 - 20:30 1.00 CMPL TN RURD CMPL TN
20:30 - 00:00 3.50 WELCTL BOPE PROD
9/7/2001 00:00 - 01 :00 1.00 WELCTL BOPE PROD
01 :00 - 03:00 2.00 WELCTL NUND PROD
03:00 - 09:30 6.50 WINDOV PULD PROD
09:30 - 11 :30
2.00 WINDOVrTRIP PROD
1.50 WINDOV OTHR PROD
3.50 WINDOVrrRIP PROD
1.00 WINDOV SETW PROD
11 :30 - 13:00
13:00 - 16:30
16:30 - 17:30
17:30 - 19:00
1.50 WINDOV CIRC PROD
2.00 WINDOV STWP PROD
19:00 - 21 :00
Start:
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
8/16/2001
Description of Operations
9 ppg brine
Hold pre-job meeting, test Dowell lines to 2
500 psi, fill DP wI 83.5 bbls 10% HCL acid,
followed with 10 bbls brine
Pump 3.2 bbls acid into each screen from 10
405' to 8890'
Load DP wI 54.5 bbls acid followed with 14.
9 bbls brine
Pump 3.2 bbls acid into each screen from 88
27' to 7627'
Load DP wI 42.5 bbls acid followed with 15.
5 bbls brine
Pump 3.2 bbls acid into each screen from 75
64' to 6807'
Load DP wI 12 bbls acid followed with 32.8
bbls brine
Pump 3.2 bbls acid into each screen from 67
44' to 6523'
TIH with DP, to place 2 7/8" tubing on botto
m, while waiting on 6 hr. acid soak
Waiting on 6 hr. acid soak, R/U equipment
to circ. out acid with clean brine
Circ. out acid with 8.9# clean brine, started
at 7.5 BPM at 1800 psi and ended 2 to 3 BP
M at 1100 psi. Total fluid circ. was 550 bbls
Circulated to 2 vacumn trucks
POOH to 1475'
Pressure test KOIV to 690 psi
POOH with 4" HWDP and DC's
POOH LID last 9 DC's and 148 jts. 2 7/8" tu
bin g
R/U to test BOP's, Pull wear bushing
Run test plug and test BOP's to 250 psi low
and 5000 psi high, test annular to 3500 psi.
Finish BOP test, 250 psi low and 5000 psi 10
w, hole taking 4 - 5 bbls fluid a hour
RID test equip., pull test plug, set wear bus
hing in well head.
P/U BHA, whipstock and associated equip.,
mills and Sperry Sun MWD. Upload MWD and
test, MWD failed, LID tool and P/U differen
t MWD and upload. Test MWD, everything ok
Hole taking 2 - 3 bbls. fluid a hour
TIH WI DC's, shallow test MWD again, TIH t
0 1492'
R/U and test KOIV to 690 psi, held ok
TIH W I Baker whipstock assembly
Orient whipstock and set in top of liner han
ger
Displace brine water out of hole and circ. dr
illing mud in hole
Mill out window from 5941' to 5945' MD, 368
0' TV D
Printed: 11/30/2001 11: 17:54 AM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
9/7/2001
918/2001
9/9/2001
(
Page 80f 15
PHILLIPS ALASKA INC.
Operations Summary Report
1 C-1 02
1 C-1 02
ROT - DRILLING
Start:
Rig Release:
Rig Number:
8/16/2001
Spud Date: 8/18/2001
End: 9/28/2001
Group:
Sub
From - To Hours Code Code Phase
21 :00 - 22:00
22:00 - 22:30
22:30 - 00:00
00:00 - 02:00
02:00 - 04:30
04:30 - 05:30
05:30 - 06:30
06:30 - 07:30
07:30 - 10:30
10:30 -11:00
11 :00 - 15:00
15:00 - 22:30
22:30 - 00:00
00:00 - 01 :00
01 :00 - 02:30
02:30 - 03:00
03:00 - 05:30
05:30 - 09:30
09:30 - 10:30
10:30 - 12:00
12:00 - 14:00
14:00 - 15:00
15:00 - 17:30
17:30 - 18:00
1.00 WINDO CIRC PROD
0.50 RIGMNT RSRV PROD
1.50 WINDO RIP PROD
2.00 WINDO RIP PROD
2.50 WELCTL EaRP PROD
1.00 WELCTL TRIP PROD
1.00 WELCTL OBSV PROD
1.00 WELCTL TRIP PROD
3.00 WELCTL EaRP PROD
0.50 WELCTL SFTY PROD
4.00 WELCTL NUND PROD
7.50 WELCTL NUND PROD
1.50 WELCTL EaRP PROD
1.00 RIGMNT OTHR PROD
1.50 RIGMNT RURD PROD
0.50 RIGMNT RSRV PROD
2.50 WAlTON EalP PROD
4.00 WELCTL NUND PROD
1.00 WELCTL BOPE PROD
1.50 WELCTL EaRP PROD
2.00 WELCTL TRIP PROD
1.00 WELCTL TRI P PROD
2.50 WINDO RIP PROD
0.50 WINDO STWP PROD
Description of Operations
Circ. hole clean, we have magnets in the po
ssum belly and screens under the discharge
of the shaker screens to catch the metal cu
ttings
Rig service, sevice top drive
TOOH to change BHA's,( this is a two run, n
ew design Baker whipstock system)
POOH for mill change, LID MWD
Pull wear bushing for Vetco Gray to look at
why wear bushing will not fit properly in wel
I head. Found well head pack off was not se
t in place, it's not sealing off between 7 5/8
" casing and 16" conductor
RIH WI 9 - 4 3/4" DC's and 19 stands of 3 11
2" DP to use as tail pipe below storm packer
Wait on 7 5/8" storm packer to be brought fr
om Baker Oil Tools in Deadhorse
RIH WI storm packer and set at 273' from su
rface
Attempt to pull packoff out off well head, re
covered the top piece of packoff
Hold pre-job safety meeting, to prepare for I
ifting and setting back the BOP's
NID BOP's
NID well head, remove packoff, had to build
tool to recover bottom part of packoff. Redr
ess hanger and N/U well head, install new p
ackoff and confirm it is in place. Test packo
ff to 5000 psi, held ok. Run wear bushing in
to wellhead and make sure everything lines
up and sets properly. Everything is as shoul
d be.
Waiting for new riser to fit under BOP's, it
was air lifted from Anchorage today and is s
up pose to be on location tonight. The riser
we presently have is to long, we have to jac
k rig up 8" to install or remove BOP's
Clean cellar area
Slip and cut drill line
Service top drive
Waiting on riser for Nabors BOP stack. Curr
ent riser was to long and rig has to be jacke
d up 8" to install and remove BOP.
N/U riser and BOP's
Test breaks made on wellhead and BOP to 2
50 psi low and 5000 psi high
Pull test plug, set wear bushing
RIH and latch onto storm packer, POOH, LID
packer
TOOH with tail pipe used below packer
TIH will new side track mill to 5940'
Ream thru and clean up window from 5941' t
Printed: 11/30/2001 11: 17:54 AM
...... ~.....
~~pHiLlJPS1
I~
t
(
Page 9 0115
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name: 1 C-1 02
Common Well Name: 1 C-1 02
Event Name: ROT - DRILLING
Contractor Name:
Rig Name:
Date From - To Hours Code Sub Phase
Code
9/9/2001 17:30 - 18:00 0.50 WINDOVI/STWP PROD
18:00 - 22:00 4.00 WINDOV~STWP PROD
22:00 - 23:00 1.00 WINDOV CIRC PROD
23:00 - 00:00 1.00 DRILL FIT PROD
9/10/2001 00:00 - 04:30 4.50 WINDOV'TRIP PROD
04:30 - 05:00 0.50 DRILL PULD PROD
05:00 - 10:30 5.50 DRILL PULD PROD
10:30 - 12:00 1.50 DRILL DEQT PROD
12:00 - 14:00 2.00 DRILL TRIP PROD
14:00 - 19:30 5.50 DRILL PULD PROD
19:30 - 22:30 3.00 DRILL TRIP PROD
9/11/2001
9/12/2001
9/13/2001
9/14/2001
22:30 - 00:00
1.50 DRILL DRLG PROD
00:00 - 08:30
08:30 - 09:00
8.50 DRILL DRLG PROD
0.50 DRILL CIRC PROD
09:00 - 09:30 0.50 DRILL TRIP PROD
09:30 - 15:00 5.50 WAlTON ORDR PROD
15:00 - 15:30 0.50 DRILL TRIP PROD
15:30 - 00:00 8.50 DRILL DRLG PROD
00:00 - 15:30 15.50 DRILL DRLG PROD
15:30 - 16:00 0.50 DRILL CIRC PROD
16:00 - 00:00 8.00 DRILL DRLG PROD
00:00 - 00:30 0.50 DRILL CIRC PROD
00:30 - 11 :30 11.00 DRILL DRLG PROD
11 :30 - 13:00 1.50 DRILL CIRC PROD
13:00 - 13:30 0.50 DRILL CIRC PROD
13:30 - 15:00 1.50 DRILL TRIP PROD
15:00 - 15:30 0.50 RIGMNT RSRV PROD
15:30 - 17:30 2.00 DRILL TRIP PROD
17:30 - 00:00 6.50 DRILL DRLG PROD
00:00 - 00:30 0.50 DRILL CIRC PROD
Start:
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
8/16/2001
Description of Operations
0 5945'
Mill from 5945' to 5971', ream thru several t
imes to clean up
Circ. sweep and bottoms up
Perform FIT to 12 ppg., 505 psi at 3590' TV
D with 9.3 ppg mud
Pump dry job, POOH, LID 4" HWDP & 4 3/4"
DC's and milling assembly
Change out saver sub and install corrosion r
in g
P/U BHA, MWD and PWD, upload MWD, TIH t
0 5000'
Test MWD tool, failed and couldn't get it wo
rking correctly.
Pump dry job, POOH
Attempt to repair MWD tool, but failed, LID
tool and P/U new tool, upload MWD, surface
test tool, OK
TIH to 5900', test MWD, everything working,
Orient tool and RIH through window and to
TD 5971', never seen a flicker on weight ind
icator going through window.
Drill ahead from 5971' to 5985' MD. 3690 TV
D. ROP in this shale is 7 to 10 FPH.
Drill from 5985' to 6063'
Circ. bottoms up, was called from town to s
hut down operations until further notice, be
cause of safety issue.
POOH 3 stands, to 5856', shut down waiting
on orders from town.
Shut down drilling operations because of fli
ght shut downs, leaving us with no medivac
if somebody should get injured
Orient tool face to go through window, TIH t
0 bottom.
Drilling from 6063' to 6155' MD, 3747 TVD.
ROP = 10.8 fph
Drilling from 6155' to 6400' MD 2.00 hrs. A
RT 9.75 hrs. AST
Circ. for PWD base line
Drilling from 6400' to 7127' MD, 3724' TVD
2.00 hrs. ART 4.75 hrs. AST
Circulate bottoms up.
Drill 6" hole f/ 7127' to 8313'(1186') (3708'
TVD) AST =.75 hrs. ART = 4.5 hrs.
Circulate bottoms up prior to wiper trip.
Monitor well, pump dry job.
POOH to 5900'.
Service rig and top drive.
RIH
Drill 6" hole f/ 8313' to 9072' (759') (3697'
TVD) AST = .75 hrs. ART = 4.6 hrs.
CBU prior to trip for ABI failure.
Printed: 11/30/2001 11 :17:54 AM
(
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name: 1 C-1 02
Common Well Name: 1 C-1 02
Event Name: ROT - DRILLING
Contractor Name:
Rig Name:
Date From - To Hours Code Sub Phase
Code
9/14/2001 00:30 - 06:30 6.00 DRILL TRIP PROD
06:30 - 10:00 3.50 DRILL TRIP PROD
10:00 - 12:00 2.00 WELCTL BOPE PROD
12:00 - 17:30
5.50 WELCTL BOPE PROD
17:30 - 19:00 1.50 WELCTL BOPE PROD
19:00 - 22:00 3.00 DRILL OTHR PROD
22:00 - 00:00 2.00 DRILL TRIP PROD
9/15/2001 00:00 - 03:00 3.00 DRILL TRIP PROD
03:00 - 12:00 9.00 DRILL DRLG PROD
12:00 - 19:30 7.50 DRILL DRLG PROD
19:30 - 00:00 4.50 DRILL CIRC PROD
9/16/2001 00:00 - 12:00 12.00 DRILL TRIP PROD
12:00 - 13:00 1.00 DRILL TRIP PROD
13:00 - 13:30 0.50 DRILL OTHR PROD
13:30 - 14:30 1.00 DRILL TRIP PROD
14:30 - 17:00 2.50 DRILL TRIP PROD
17:00 - 19:00 2.00 RIGMNT RURD PROD
19:00 - 19:30 0.50 DRILL TRIP PROD
19:30 - 20:30 1.00 RIGMNT RSRV PROD
20:30 - 00:00 3.50 DRILL SFTY PROD
9/17/2001 00:00 - 17:30 17.50 DRILL SFTY PROD
17:30 - 18:30 1.00 RIGMNT RSRV PROD
Page 10 of 15
Start:
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
8/16/2001
Description of Operations
POOH wet. Hole in good condition.
ABI faulty. Download MWD. LID motor. PU m
otor. Check ABI (OK). LID hang off sub. Sta
nd back motor, MWD and float sub.
Pull wear bushing. RU for BOPE weekly test.
Waived by AOGCC inspector Jeff Jones. Te
st Annular to 250 psi low and 3500 psi high.
Test upper pipe rams(3 1/2' x 6" VBR), cho
ke line valves, 1,2,3 kill and HCR valves, u
pper IBOP to 250 psi low and 5000 psi high.
Test 4-16, HCR & manual kill line valve, low
er top drive valve, 4" floor safety valve, 3 1
12" IF floor safety valve, 4" IBOP, 3 1/2" IF
IBOP to 250 low and 5000 psi high. Tested I
ower pipe rams(2 7/8" x 5" VBR) to 250 and
5000 psi with 3 1/2" and 4". Upper ramss (3
1/2" x 6" VBR) were tested with both 3 1/2"
and 4" also.
RID test equipment. Run wearbushing. Blowd
own choke manifold.
MU BHA. Change stabilizer on motor. Adjust
angle on motor to 1.5 deg. Orient motor wi
th MWD. Program Sperry tools.
RIH wI 6" bit and BHA # 13. Shallow test OK
. RIH to +1- 5900'.
Trip in hole to window. Orient for entrance.
Continue to RIH. Precautionary ream 90' to
bottom.
Drill 6" hole from 9072' to 10017'(945') (TV
D= 3693') ART =.3 hrs. AST = 1.5 hrs.
Drill 6" hole from 10017' to 10600' (583') (T
VD= 3688')
Circulate and condition mud and hole. Chan
ge out mud system.
POOH, SLM, wet, tight f/ 6326' to window. P
ump f/ 6232' to 5985'. Continue POOH, down
load MWD. LID pulsar & hangoff sub.
LID BHA
Retreive corrosion ring f/ saver sub on top
d r i v e.
MU 6" Hole opener assembly.
RIH to casing window.
Slip and cut drilling line. Service rig and to
p drive.
Start to continue and go out window. Notice
d keeper out of grabs.
Change out grab heads on top drive. Floorha
nd injured both hands.
Injury while changing die blocks. Safety sta
nd down.
Safety stand down. Injury while changing gr
abs on top drive.
Finish replacement of grabs on top drive.
Printed: 11/30/2001 11: 17:54 AM
t'
.... ...... .....
~~PHILLlPS1
~
{
PHILLIPS ALASKA INC.
Operations Summary Report
Page 11 of 15
Legal Well Name: 1 C-1 02
Common Well Name: 1 C-1 02
Event Name: ROT - DRILLING
Contractor Name:
Rig Name:
Date From - To Hours Code Sub Phase
Code
9/17/2001 18:30 - 19:00 0.50 DRILL REAM PROD
19:00 - 00:00 5.00 DRILL REAM PROD
9/18/2001 00:00 - 09:00 9.00 DRILL REAM PROD
09:00 - 11 :30 2.50 DRILL CIRC PROD
11 :30 - 15:30 4.00 DRILL TRIP PROD
15:30 - 16:00 0.50 RIGMNT RSRV PROD
16:00 - 18:30 2.50 DRILL TRIP PROD
18:30 - 23:00 4.50 DRILL CIRC PROD
23:00 - 00:00 1.00 DRILL CIRC PROD
9/19/2001
00:00 - 03:00
3.00 DRILL CIRC PROD
03:00 - 10:00 7.00 DRILL TRIP PROD
10:00 - 10:30 0.50 DRILL CIRC PROD
10:30 - 16:00 5.50 DRILL TRIP PROD
16:00 - 00:00 8.00 DRILL TRIP PROD
9/20/2001 00:00 - 02:30 2.50 CMPL TN TRIP PROD
02:30 - 03:30 1.00 CMPL TN CIRC PROD
03:30 - 05:00 1.50 CMPLTN CIRC PROD
05:00 - 07:00 2.00 CMPLTN CIRC PROD
07:00 - 08:30 1.50 CMPL TN AWSH PROD
08:30 - 10:00 1.50 CMPLTN CIRC PROD
10:00 - 17:00 7.00 CMPL TN TRIP PROD
17:00 - 17:30 0.50 CMPL TN TRIP PROD
17:30 - 18:00 0.50 RIGMNT RSRV PROD
18:00 - 20:30 2.50 CMPLTN TRIP PROD
20:30 - 21 :00 0.50 RIGMNT OTHR PROD
21 :00 - 00:00 3.00 CMPL TN TRIP PROD
9/21/2001 00:00 - 01 :00 1.00 CMPL TN TRIP PROD
Start:
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
8/16/2001
Description of Operations
Circulate out through window to 6000'.
Ream 6" upper lateral hole, with hole open
er assembly. Ream each stand down and up,
then circulate each stand down.
Ream fl 8023' to 10600' with 6" hole opener
assembly.
Circulate and condition mud.
Short trip to casing window @ 5941'. Hole in
good shape.A little excess drag @ 6250'-6
450' area of hole.
Service rig and top drive.
RIH. Precautionary ream fl 6250' to 6450'. D
id not see any problems. Continue to TD.
Circulate sweep and condition hole.
Pump 30 bbl push pill. Flush surface lines w
I w ate r (1, 2 ,3 P u m P s - c h 0 k e ma n if 0 I d - kill I
ine- cement standpipe- 3 sections of hose 0
n floor)
Circulate 600 bbls filtered brine @ 8.9 ppg
while displaceing mud from hole. Follow wit
h 290 bbls viscosified brine, displaced with
41 bbls filtered brine, leaving viscosified br
ine in open hole.
PJSM. Monitor well. Blow down top drive. P
OOH to 4753'. Work through tight spots @ 6
323', 6097' and 5944'. Max 10 k overpull.
Circulate viscosified brine out of hole (Clea
ning up drill pipe).
PJSM, monitor well, blow down top drive. LI
D 3 1/2" drill pipe & BHA.
MU BHA with dual 7 5/8" casing scrapers. RI
H wI 3 1/2" DP, HWDP, and 4 3/4" drill colla
r s .
PU 3 12" HWDP and 4 3/4" DC's to run dual
scrapers.
CBU, check ntu's of filtered brine.
RU, PJSM, Pump caustic wash taking return
sf/well head to vac truck for disposal of c
austic wash.
Circulate, checking ntu's. Came down to 22
ntu's.
RU, PJSM, Pump acid wash wI Dowell, takin
g returns to outside open top slop tank.
RU, pump brine, check ntu's. Pump 215 bbls
viscosified brine.
Drop rabbit, monitor well, POOH wet.
LID BHA
Safety meeting, Service top drive.
MU BHA to fetch whipstock.
Adjsut kicker cylinder clamps on bales for t
op drive.
RIH to retreive whipstock.
Trip in hole to 5947' with whipstock retrieva
Printed: 11/30/2001 11:17:54 AM
~.
- ~
~~PHILLIPS~.
~
{
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name: 1 C-1 02
Common Well Name: 1 C-1 02
Event Name: ROT - DRILLING
Contractor Name:
Rig Name:
Date From - To Hours Code Sub Phase
Code
9/21/2001 00:00 - 01 :00 1.00 CMPLTN TRIP PROD
01 :00 - 02:00 1.00 CMPL TN OTHR PROD
02:00 - 03:00 1.00 CMPL TN CIRC PROD
03:00 - 06:30 3.50 CMPLTN TRIP PROD
06:30 - 10:00 3.50 CMPLTN TRIP PROD
10:00 - 12:00 2.00 CMPL TN RURD PROD
12:00 - 17:30 5.50 CMPL TN RUNT PROD
17:30 - 19:30 2.00 CMPL TN RUNT PROD
19:30 - 00:00 4.50 CMPL TN RUNT PROD
9/22/2001 00:00 - 02:00 2.00 CMPL TN RUNT PROD
02:00 - 04:30 2.50 CMPL TN RUNT PROD
04:30 - 05:30
1.00 CMPL TN OTHR PROD
05:30 - 13:00
7.50 CMPL TN RUNT PROD
13:00 - 16:30
3.50 CMPL TN RUNT PROD
16:30 - 00:00 7.50 CMPLTN TRIP PROD
9/23/2001 00:00 - 03:30 3.50 CMPLTN TRIP PROD
03:30 - 10:30 7.00 CMPLTN TRIP PROD
10:30 - 11 :30 1.00 RIGMNT RSRV PROD
11 :30 - 13:00 1.50 WELCTL OTHR PROD
13:00 - 18:30
5.50 WELCTL BOPE PROD
18:30 - 20:00
1.50 WELCTL OTHR PROD
20:00 - 20:30
0.50 RIGMNT RSRV PROD
Page 12 of 15
-
Start:
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
8/16/2001
Description of Operations
I too I,
Workover and engage whipstock. Pull free w
ith 52k overpull.
CBU
Monitor well. Blow down TD. POOH -(slow/w
e t)
LID MWD, BHA, Whipstock, subs & x-o's. CI
ear rig floor.
PJSM. RU casing tools and equipment to run
4" screens and blanks for upper lateral.
Safety meeting. Run 4" screens and blanks.
Run 4061.91')
Change elevators. Run 4 1/2" blanks and 2-
ECP's . Total length of 539.42')
Run 2 7/8" inner circulating string inside lin
er. 110 jts in hole (3282.27')
Run 2 7/8" inner circulating string (152 join
ts run + 0.8'). Tagged pack off @ 4562.26'. B
ottom out @ 4575.46'. (152 jts + 14')
Space out with 2 7/8" pups and MWD collar
& x-o's. Ran 151 jts 2 7/8" + 7.87 pup' + 7.8
6' pup+ collars and x-o's(19.90) to leave bo
ttom of slick stick @ 4569.58' (approx 7 1/2'
into packoff bushing).
Change saver sub on TD from 4 1/2" IF box
by 4" HT38 to 4 1/2" IF box by 3 1/2"IF pin
so if needed to circ.
Trip in hole with 4" liner. Fill every stand.
Determine actual up and down weight every
5 stands while running.
Orient & set flanged hook hanger in window.
Drop 1-1/2" ball, pump down & pressure to
2700 psi & release running tool. Pressure to
3700 psi to blow ball seat.
LID all 3 1/2" IF work string.
LID 3 1/2" HWDP and 3 1/2" drill pipe after
setting flange hook in casing window.
Monitor well. PJSM, RU & lay down MWD col
lar and 2- 7/8" inner circulating string.
Change top drive saver sub from 4 1/2" IF t
0 3 1/2" IF to 4 1/2" IF to 4" HT38 for 4" dri
II pi P e.
Pull wear bushing, Rig up for weekly BOPE t
est. Verbal extension was given byAOGCC in
sp. Chuck Sheve to test after liner was in h
ole.
Weekly BOPE test. Test witnessed by AOGC
C rep. John Spaulding. Test annular @ 250
psi low and 3500 psi high. Test all other pie
ces @ 250 psi low and 5000 psi high.
RID test equipment. Blow down lines. Install
wear bushing.
Service top drive and rig.
Printed: 11/30/2001 11: 17:54 AM
~ ...... ~
1~piiiLùP~
~
(
(
PHILLIPS ALASKA INC.
Operations Summary Report
15:00 - 16:00 1.00 CEMENl PUMP PROD
16:00 - 17:00 1.00 CEMENl OTHR PROD
17:00 - 21 :00 4.00 CEMENl TRIP PROD
21 :00 - 00:00 3.00 CMPLTN TRIP PROD
9/25/2001 00:00 - 04:00 4.00 CMPL TN TRIP PROD
04:00 - 09:00 5.00 CMPL TN TRIP PROD
09:00 - 11 :00 2.00 CMPL TN CIRC PROD
11 :00 - 12:00 1.00 CMPL TN RURD PROD
12:00 - 12:30 0.50 CMPLTN SFTY PROD
12:30 - 15:30 3.00 CMPL TN AWSH PROD
Legal Well Name: 1 C-1 02
Common Well Name: 1 C-1 02
Event Name: ROT - DRILLING
Contractor Name:
Rig Name:
Date From - To Hours Code Sub Phase
Code
9/23/2001 20:30 - 21 :30 1.00 CMPL TN TRIP PROD
21 :30 - 00:00 2.50 CMPL TN TRIP PROD
9/24/2001 00:00 - 02:30 2.50 CMPL TN TRIP PROD
02:30 - 03:30 1.00 CMPL TN OTHR PROD
03:30 - 06:00 2.50 CMPLTN TRIP PROD
06:00 - 08:00 2.00 CEMENl TRIP PROD
08:00 - 11 :30 3.50 CEMENl TRIP PROD
11 :30 - 13:00 1.50 CEMENl OTHR PROD
13:00 - 15:00 2.00 CEMENl PUMP PROD
15:30 - 17:30
2.00 CMPLTN TRIP PROD
17:30 - 21 :30
21:30 - 00:00
4.00 CMPL TN TRIP PROD
2.50 CMPLTN AWSH PROD
Page 13 of 15
Start:
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
8/16/2001
Description of Operations
PU and MU running tool & diverter to get int
0 top lateral.
RIH total of 33 stands 4" drill pipe @ midni
ght. Run @ 2 min per stand.
RIH wI 4" drill pipe and diverter to TOL @ 5
936'. Set Diverter 2' into TOL @ 5938'.
Set diverter. PU wt 140 k SO wt 110 K
Monitor well. Blow down TD. POOH. LID runn
ing tools.
PJSM. RU tbg tools to PU 18 joints of 2 7/8"
tbg. and assembly to cement upper and low
er ECP's.
RIH wI cement inflation tools to inflate uppe
r and lower external casing packers.
Drop ball and pump to seat @ 6430'. Pressu
re test cups to 1500 psi fl 10 min. OK. Pres
sure to 3100 psi to blow seat.
PJSM. RU cement equipment. Test Dowell to
5000 psi. Load string wI cement, cement low
er external casing packer. Took 3/8 bbls ce
ment in packer = 7" open hole.
POOH to 6043', RU to inflate upper external
casing packer. Put 1 3/4 bbls cement in pa
cker= 11" open hole.
PU to 5927'. Reverse out excess cement.
Pooh wI 4" dp and 18 joints of 2 7/8" tbg an
d inflation tools.
PJSM. RU to make up screen washing assem
bly. PU 2 7/8" tbg on assembly and RIH wI 2
7 I 8".
P/U 153 jts. of 2 7/8" Tubing and RIH - RID
Tubing handling equipment
RIH WI 4" DP to 10524'
Displace hole with 8.9 ppg filtered brine, 60
0 bbbls.
R/U Dowell Schlumberger for acid wash
Hold pre-job safety meeting, test lines to 50
00 psi
Pump 82 bbls 10% Hcl acid into work string,
displace 10 bbls of acid out into open hole
with 8.9 brine. Attempt to rig down Dowell Ii
nes from work string, well was U-tubing up
work string, with acid close to surface. Rig
back Dowell lines. Check acid weight coming
out of transport and found it to be on the I
ight side of 8.8 ppg and the brine is a 8.9+.
Reverse acid back out of work string into 0
pen top tank.
POOH 42 stands, above where our last wash
will be pumped and place a float in string.
TIH at 2 mins per std., fill every 10 stands
Pump 82 bbls 10% Hcl acid, displace 10 bbl
s of acid into open hole, start acid wash on
Printed: 11/30/2001 11: 17:54 AM
..... """"'" .....
~~PHILLlPS 1
~
~
{
(
Page 14 of 15
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
9/25/2001
9/26/2001
1 C-1 02
1 C-1 02
ROT - DRILLING
Sub
From - To Hours Code Code Phase
21 :30 - 00:00
2.50 CMPL TN AWSH PROD
00:00 - 05:00
5.00 CMPLTN AWSH PROD
05:00 - 07:00
07:00 - 08:30
08:30 - 11 :00
2.00 CMPLTN TRIP PROD
1.50 RIGMNT RURD PROD
2.50 CMPL TN RURD PROD
11 :00 - 13:00
2.00 CMPLTN CIRC PROD
13:00 - 16:30 3.50 CMPLTNTRIP PROD
16:30 - 22:00 5.50 CMPL TN TRIP PROD
22:00 - 22:30 0.50 CMPL TN RURD PROD
22:30 - 00:00 1.50 CMPLTN TRIP PROD
9/27/2001 00:00 - 01 :00 1.00 CMPLTN TRIP PROD
01 :00 - 02:00 1.00 CMPL TN TRIP PROD
02:00 - 06:30 4.50 CMPL TN TRIP PROD
06:30 - 07:30 1.00 CMPL TN RURD PROD
07:30 - 08:30 1.00 CMPL TN RURD PROD
08:30 - 16:00 7.50 CMPLTN TRIP PROD
16:00 - 21 :30 5.50 CMPL TN RURD PROD
Start:
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
8/16/2001
Description of Operations
screens from 10443' to 9357'. At report time
17 screens had been washed with 3.8 bbls
acid per screen
Acid wash screens F/9357' to 8853',6 - scre
ens., Pump 69 bbls 10% Hcl in work string,
displace to end of tubing, acid wash screens
F/8853' to 7541',19 screens., Pump 52 bbl
s 10% Hcl in work string, displace to end of
tubing, acid wash F/7541' to 6535',15 scre
ens. Displace +- 3.8 bbls acid per screen at
3 bbl per min. Pull float out of string.
TIH to 10524, wait on acid soak
Hold pre-job meeting, slip and cut drill line
Assemble and test to 5000 psi the 2 piece V
etco Gray tubing hanger, redress hanger wit
h new outer seals. Hold pre-job for displaci
ng acid out of hole
Displace acid out of hole with 8.9 ppg filter
ed brine. Displaced to vacumn trucks. Total
pumped 650 bbls. at rates from 8 bbls per m
in to 3 bbls per min.
POOH W/4" DP
Hold pre-job for R/U and pulling of 2 7/8" tu
bing Change handling tools to 2 7/8" tubing
POOH LID 153 jts of 2 7/8" tubing
Hold pre-job, change handling equip. back t
0 4"
P/U spear and TIH to latch onto diverter ass
embly
New crew held pre-job meeting, TIH with spe
ar
Latch onto diverter, took several try's, but c
aught it by circ. into it, took 20K overpull t
0 pull loose.
Held pre-job meeting, TOOH w/diverter, rele
ase spear from diverter and LID
Held pre-job meeting, pull wear bushing, ha
d trouble getting it through Hydril annular
R/U to run 4 1/2" kill string, hold pre-job m
eeting
TIH with 4 1/2" kill string
Held pre-jb meeting, attempt to hang off tub
ing hanger, couldn't get it through the top 0
ff 13 5/8" annular, after several attempts it
was decided to pull bell nipple and look for
the problem, held pre-job meeting, pull bell
nipple, found that the wear ring on top of an
nular rubber was smaller than the Vetco Gra
y hanger, hanger OD is 13.450" and annular
wear ring should have been 13.625". held pr
e-job meeting, made proper safety precautio
ns and ground the wear ring to the proper si
ze
Printed: 11/30/2001 11 :17:54 AM
.... ....... ~
/ - -:\
\ ,PH ILLlPS ~
~)
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
9/27/2001
9/28/2001
(
{
PHILLIPS ALASKA INC.
Operations Summary Report
1 C-1 02
1 C-1 02
ROT - DRILLING
Page 15 of 15
Start:
Rig Release:
Rig Number:
Spud Date: 8/18/2001
End: 9/28/2001
Group:
8/16/2001
Sub
From - To Hours Code Code Phase
21 :30 - 23:00
23:00 - 00:00
00:00 - 03:00
03:00 - 06:00
06:00 - 09:00
09:00 - 10:00
1.50 CMPL TN RURD PROD
1.00 CMPL TN NUND PROD
3.00 CMPLTN NUND PROD
3.00 CMPLTN NUND PROD
3.00 CMPLTN FRZP PROD
1.00 CMPL TN RURD PROD
Description of Operations
Run tubing hanger through BOP's and land i
n wellhead with no problems, test hanger to
5000 psi., LID landing jt., set BPV. Ran
a total of 190 jts of 4 1/2" 12.6# L-80 NSCT
tubing with a 4 1/2"x2" swage, w
ith a 1.5" ID on bottom, plus a tubing hang
er with a 30' 4 1/2" hanger jt baker locked 0
n it. Kill string is set at 5845' RKB
Held pre-job meeting, NID BOP's
NID BOP's and layout drilling spool
N/U Vetco Gray tree and test to 5000 psi
Freeze protect well by pumping 110 bbls die
sel down annulus and letting it u-tube back
through tree. Had 150 psi on both tubing an
d annulus when complete.
Rig up lubricator on tree and set BPV, Rig d
own lubricator. Release rig at 10:00 hrs. 9/2
8/01. Finish rig down to move to 1 c-131
Printed: 11/30/2001 11: 17:54 AM
~ ~ -
.'PHILlIPS ~
~
(
('
Page 1 of 3
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name: 1 C-1 02
Common Well Name: 1 C-1 02
Event Name: WORKOVER/RECOMP
Contractor Name: n1433@ppco.com
Rig Name: Nordic 3
Date From - To Hours Code Sub Phase
Code
10/9/2001 00:00 - 01 :00 1.00 MOVE MOB MOBMIR
01 :00 - 12:00 11.00 MOVE MOBMIR
12:00 - 13:00
1.00 CMPL TN OTHR CMPL TN
13:00 - 16:00
16:00 - 21 :30
3.00 CMPLTN NUND CMPLTN
5.50 CMPLTN OTHR CMPLTN
21 :30 - 22:30 1.00 CMPLTN CIRC CMPL TN
22:30 - 00:00 1.50 WELCTL BOPE CMPLTN
10/10/2001 00:00 - 07:30 7.50 WELCTL EaRP CMPL TN
07:30 - 08:30 1.00 WELCTL BOPE CMPL TN
08:30 - 09:30 1.00 CMPLTN CIRC CMPL TN
09:30 - 10:30 1.00 WELCTL BOPE CMPL TN
10:30 - 11 :00 0.50 CMPL TN OTHR CMPL TN
11 :00 - 11 :30 0.50 CMPL TN PULD CMPL TN
11 :30 - 12:00 0.50 CMPL TN OBSV CMPL TN
12:00 - 13:00 1.00 CMPL TN OTHR CMPL TN
13:00 - 17:30 4.50 CMPL TN PULD CMPL TN
17:30 - 19:30 2.00 CMPL TN RURD CMPL TN
19:30 - 21 :00 1.50 CMPL TN RURD CMPL TN
21 :00 - 00:00 3.00 WAlTON EalP CMPL TN
10/11/2001 00:00 - 09:30
09:30 - 10:30
9.50 WAlTON EalP CMPL TN
1.00 CMPL TN OTHR CMPL TN
Start: 10/9/2001
Rig Release: 10/13/2001
Rig Number: 3
Spud Date: 8/18/2001
End:
Group:
Description of Operations
Continue to move rig to 1C location. [on p
ad @ 0100 hrs]
Conduct minor maintenance on rig. Inspect
well hd area. Prepare pad site for rig. Mov
e in au x equip as per opportunity. Move rig
over, center rig & level same. Berm up aro
und rig, complete spotting of aux equip. A
ccept rig for duty 1200 hrs 10/09/2001
Back pressure valve previously set. Ck ann
ulus pressure @ 100 psi, bleed off 17 bbl d
iesel, pressure to zero on both sides. Very
small leak in bpv.
ND tree I NU 13 5/8" x 5k psi bope.
X-out lower pipe rams to 4.5", rig up circula
tion lines to cellar & flush all mud lines wI
fw. Clean pits [prepare to receive 3% kcl w
t r] .
Circulate 90 bbl 3% kcl down tbg @ 1.5 bpm
1200 psi [bpv in place]. Pull bpv. Install
Idg jt & mu choke lines.
Test bope.
Complete replacement of inside manual chok
e valve & hcr valve.
Unable to obtain test on Blind rams.
Pull bpv. Pump 90 bbl 8.9 ppg kcl down tbg,
recover freeze protect diesel ffrom annulus
, ck tbg dead.
set two way ck, test blind rams.
Recover two way ck, install Idg jt in hanger,
back out lock down bolts.
Pull hanger from bowl wI 70k Ibs[10 over cal
culate4d of 60k Ibs], pull hanger to floor & I
d hanger & Idg jt.
fill hole wI 20 bbl 8.9 ppg kcl wtr, observe f
or 30 minutes, determine losses to hole @ 6
0 bbl I hr. Note: 8.9 ppg kcl kill brine dete
rmined from last kill wt fluid used to work w
ell [rpt 42, 27 Sept].
water remaining surface volume to 8.7 ppg,
continue to fill hole.
Pooh wI 4.5" kill string. Losses decreased t
0 12 bph. Total losses on trip out = 66 bbl.
MI crane & load ESP running equip to pipe s
h ed.
Rig up floor for ESP completion.
Wait on central lift to prerpare equipment.
Continue to monitor brine losses to hole @
12 bph. Total losses to hole since starting
ops = 163 bbl.
WO Centrilift equip I personnel.
Off load Certrilift equip & transfeer to pipe
shed.
Printed: 11/30/2001 11:20:24 AM
---- ....... ~
~'PHiLLiPs1
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
(
(
PHILLIPS ALASKA INC.
Operations Summary Report
1 C-1 02
1 C-1 02
WORKOVER/RECOMP
n1433@ ppco.com
Nordic 3
Date From - To Hours Code Sub Phase
Code
10/11/2001 10:30 -11:00 0.50 CMPL Tf\ SFTY CMPL TN
11:00 -12:00 1.00 CMPL TN PULD CMPL TN
12:00 - 16:30 4.50 CMPLTN OTHR CMPL TN
16:30 - 17:30 1.00 CMPLTN PULD CMPL TN
17:30 - 18:30 1.00 CMPL TN PULD CMPL TN
18:30 - 21 :00 2.50 CMPL TN OTHR CMPL TN
21 :00 - 22:00 1.00 CMPL TN SUN CMPL TN
22:00 - 23:00 1.00 CMPL TN DEaT CMPL TN
23:00 - 00:00 1.00 CMPL TN PULD CMPL TN
10/12/2001 00:00 - 16:00
16:00 - 17:00
17:00 - 00:00
10/13/2001 00:00 - 04:00
04:00 - 05:30
16.00 CMPL TN RUNT CMPL TN
1.00 CMPL TN RUNT CMPL TN
7.00 CMPLTN OTHR CMPLTN
4.00 CMPL TN DEaT CMPL TN
1.50 CMPLTN OTHR CMPLTN
Page 2 of 3
Start: 10/9/2001
Rig Release: 10/13/2001
Rig Number: 3
Spud Date: 8/18/2001
End:
Group:
Description of Operations
PJ S M
Position equip I sensors in protected jt of 4
.5" tbg for pick up.
Modify 4 cable clamps to accomodate motor
power line, & temp I pressure gages.
PU - MU press I temp subs, motor lead sub,
testing same as per program.
After making up discharge temp head to sen
or leads noted an effective od of the ESP st
ring @ this point to be 6.75" & sensor head
portruding upward @ a 60? angle as design
ed [id of csg = 6.75"]. Consult wI ppco ICe
ntrilift engineer & opt not to run same as an
active tool. Remove terminator from senso
r housing, cap off wI "0" ring fitted blankin
g cap & silicon sealer.
Make final fitting of one cable clamp to furt
her reduce od.
PJSM Rig up slick line, tih wI pump assmby
& pack off [required three trips - normal]
RU & test pump - equip to 1000 psi ./15 m
in & rd test gear.
Continue to rih wI ESP completion, installin
g clamps & testing as per program. @ GLM
@ Midnight. Continue to load hole wI 3%
KCL wtr, rate @ rpt time = 3.5 bph. Total
fluid lost last 24 hrs = 74.5 bbl Total lost s
ince start ops = 237.5 bbl
Continue to run completion as per program.
Testing continuity each 10 strands run. In
stalling Cannon single channel clamps over
specilized tublar equipment as per program
to 5 jts above the GLM, then one every othe
r jt to start of heat trace. Cannon dual cha
nnel clamps are run from the start of the he
at trace to surface providing full protection
of the heat trace & motor power cable. Sta
rt heat trace 15' above pin end of jt # 89 [3
050'md I 2228' tvd].
PU hanger, redress same & check alighment
of hanger discharge port. Ck up wt of 105k
Ibs & slack off of 55k.
Run continuity cks prior to heat trace cable
splice. Make heat trace splice. Splices inc
omplete @ rpt time. Fluid lost to well last
24 hrs = 65 bbl Total to well since start u
p = 302.5 b b I
Cut ESP cable, make continuty ck, mu conne
ction & retest connection & penetrators. In
stall final clamps on hanger jt. Refer to E
SP TBG detail for cable clamp inventory in
well dated 10/13/2001.
Land out completion, run in lock down bolts.
Printed: 11/30/2001 11 :20:24 AM
..... ...... ~
(PHilLIPS ~
I[Ø
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
10/13/2001 04:00 - 05:30
From - To
05:30 - 07:30
07:30 - 09:30
09:30 - 10:30
10:30 - 11 :30
11 :30 - 13:30
('"
(
Page 3 of 3
PHILLIPS ALASKA INC.
Operations Summary Report
1 C-1 02
1 C-1 02
WORKOVER/RECOMP
n1433@ppco.com
Nordic 3
Sub
Hours Code Code
1.50 CMPLTN OTHR CMPLTN
Phase
2.00 CMPL TN NUND CMPL TN
2.00 CMPL TN NUND CMPL TN
1.00 CMPL TN SEaT CMPL TN
1.00 CMPL TN DEaT CMPL TN
2.00 CMPLTN FRZP CMPLTN
13:30 - 14:30 1.00 CMPLTN OTHR CMPL TN
14:30 - 15:30 1.00 CMPL TN OTHR CMPL TN
15:30 - 17:00 1.50 CMPL TN OTHR CMPL TN
17:00 - 19:00 2.00 CMPL TN OTHR CMPL TN
Start: 10/9/2001
Rig Release: 10/13/2001
Rig Number: 3
Spud Date: 8/18/2001
End:
Group:
Description of Operations
Test hanger & sleeve body to 5k psi 115
min. Ld Idg jt & set bpv.
Nd bope.
NU & test void to 5k psi I 15 min.
Pull bpv. Set test plug & test tree to 5k psi
115 min, pull test plug.
Make final continuity checks [motor, heat tr
ace penetrators].
Freeze protect wI 145 bbl diesel. Pump 145
bbl diesel down annulus @ 2.5 bpm 300 - 4
75 psi. Manifold annulus & tbg via choke &
allow to u-tube. Equalized fluid levid = 240
8' tvd I 3508' md.
SICP I SITP = 280 psi. Slow down pump & Ii
n es.
Set bpv, secure tree.
Move rig off well, remove mats & clean I pol
ice cellar & area under rig mats & vicinity.
Continue to prepare rig for move I WO Field
Wide crew change & clearance from securit
y to move on road. Fluid lost to well last
24 hrs = 47.5 bbl total lost to well since st
art up = 351 bbl Rig off well @ 1500 hrs 1
0/13/2001 Rig released For move @ 1900 hr
s Rig off location @ 2000 hrs
Prinled: 11/30/2001 11 :20:24 AM
Date
10/08/01
10/11/01
1 0/24/01
11/22/01
(
1 C-1 02 Event H ¡story
('
Comment
DRIFT TBG W/ 3.810M X 47' DUMMY PUMP, TAGGED TOP OF SWAGE @ 5845' RKB PICK UP WT 1100#
COMPLETE. [ESP WORK]
SET 3.80M 00 X 39' 7M CENTRIFICAL ESP- 3.75n 00 X 8' PACK OFF ASS'Y & TBG STOP ON NORDIC RIG
@ 139' RKB. [ESP WORK]
INSTALLED 2000# TBG TO CSG SOY @ 5662' RKB. SBHP @ 5785' WLM. [PRESSURE DATA, GLV]
CENTRILlFT TECH ABLE TO GET MOTOR RUNNING, COMPLETE [ESP WORK]
Page 1 of 1
11/30/2001
Re: 19.:-102 Sundry - Change in Procedure
, .
('
('
Subject: Re: 1 C-1 02 Sundry - Change in Procedure
Date: Wed, 10 Oct 2001 18:18:13 -0800
From: "Steve McKeever" <smckeev@ppco.com>
To: tom_maunder@admin.state.ak.us
CC: "Sharon Allsup-Drake" <sallsup@ppco.com>, 'Todd J Mushovic" <tmushov@ppco.com>
Tom:
~()\-\fo\ ~t)\-\"";).
Nordic Rig 3 has moved onto 1C-102/1C-102L 1 late last night, and is in
the process of running the ESP completion as was originally permitted.
Steve McKeever
Drilling Engineer
Phillips Alaska, Inc.
907.265.6826 office
907.265.1535 fax
907.275.0369 pager
smckeev@ppco.com
lilt is better to keep your mouth shut and appear stupid than to open it and
remove all doubt."
- Mark Twain
----- Forwarded by Steve McKeever/PPCO on 10/10/01 06:22 PM -----
Tom Maunder <tom_maunder@admin.state.ak.us>
09/20/01 05:04 AM
To: Steve McKeever/PPCO@Phillips
cc:
Subject:
Re: 1 C-1 02 Sundry .. Change in Procedure
Steve,
Your program looks acceptable and you have approval to proceed. You are
correct a sundry
will be necessary. Thanks for providing an estimate of when the rig would
move back.
When operations resume, please send us an email giving notice.
Tom Maunder, PE
Sr. Petroleum Engineer
Steve McKeever wrote:
> Hi Tom:
>
> re: West Sak Multilateral We1/1C-102 / 1C..102L 1, Permits # 201-161,
> 201..172
>
1of3
10/11/01 12:22 PM
Re: 19-102 Sundry - Change in Procedure
("
> Due to a delivery problem with a down hole sensor we would like
> authorization for a completion procedure other than the one permitted for
> the above well.
> We had planned to run the ESP completion at the usual time, at the end of
> the drilling phase, before the rig moves off. We are hoping that the
AOGCC
> will authorize us to suspend our operations on this well, move off, then
> move back on in late November to run the ESP.
>
> The attached file details the proposed changes in procedure, with a
> schematic showing the well as it would be "suspended".
>
> If this alternative procedure is acceptable to the Commission, can you
> please provide authorization via e-mail? Should you provide such
> authorization we will follow up with a formal Application for Sundry
> Approval, should you require it.
>
> We are expecting to move off of this well sometime early next week.
>
> (See attached file: 1C-102L 1 Sundry Procedure change.pdt)
>
> Steve McKeever
>
>
>
>
>
>
>
>
> "It is better to keep your mouth shut and appear stupid than to open it
and
>
> remove all doubt. "
> .. Mark Twain
>
>
(
Drilling Engineer
Phillips Alaska, Inc.
907.265.6826 office
907.265. 1535 fax
907.275.0369 pager
smckeev@ppco.com
---"--"----,,,,,,------------.------II1II-------------------------.-------..----
>
Procedure change.pdf
> 1C-102L 1 Sundry Procedure change.pdf
( application/pdt)
> Encodmg:base64
(See attached file: tom_maunder.vcf)
Name: 1 C-1 02L 1 Sundry
Type: Acrobat
r----.
~Tom Maunde-r <tom maunder(Ø;dmin.state.~k.us> .1
Sr. Petroleum Engineer
Alaska Oil and Gas Conservation Commission I
20f3
10/11/0112:22 PM
Re: 1C-102 Sundry - Change in Procedure
(
,1
(
Subject: Re: 1C-102 Sundry .. Change in Procedure
Date: Thu, 20 Sep 2001 05:04:29 -0800
From: Tom Maunder <tom_maunder@admin.state.ak.us>
To: Steve McKeever <smckeev@ppco.com>
Steve,
Your program looks acceptable and you have approval to proceed. You are correct a sundry
will be necessary. Thanks for providing an estimate of when the rig would move back.
When operations resume, please send us an email giving notice.
Tom Maunder, PE
Sr. Petroleum Engineer
Steve McKeever wrote:
> Hi Tom:
>
> re: West Sak Multilateral We1l1C-102 / 1C-102L 1, Permits # 201-161,
> 201-172
>
> Due to a delivery problem with a down hole sensor we would like
> authorization for a completion procedure other than the one permitted for
> the above well.
> We had planned to run the ESP completion at the usual time, at the end of
> the drilling phase, before the rig moves off. We are hoping that the AOGCC
> will authorize us to suspend our operations on this well, move off, then
> move back on in late November to run the ESP.
>
> The attached file details the proposed changes in procedure, with a
> schematic showing the well as it would be "suspended".
>
> If this alternative procedure is acceptable to the Commission, can you
> please provide authorization via e..mail? Should you provide such
> authorization we will follow up with a formal Application for Sundry
> Approval, should you require it.
>
> We are expecting to move off of this well sometime early next week.
>
> (See attached file: 1C-102L 1 Sundry Procedure change.pdf)
>
> Steve McKeever
>
>
>
>
>
>
>
>
> "It is better to keep your mouth shut and appear stupid than to open it and
>
> remove all doubt. "
> .. Mark Twain
>
Drilling Engineer
Phillips Alaska, Inc.
907.265.6826 office
907.265. 1535 fax
907.275.0369 pager
smckeev@ppco.com
> -"'''---'''---------''''--'''---'''------''''''''---''''-''''''--'''----'-------'''''-fI''!........-----..--
1of2
9/20/01 5:44 AM
Re: 1 C-1 02 Sundry - Change in Procedure
>
>
>
t
Name: 1C-102L 1 Sundry Procedure change.pdf
1C-102L 1 Sundry Procedure change.pdf Type: Acrobat (application/pdt)
Encoding: base64
Tom Maunder <tom maunder@admin.state.ak.us>
SL Petroleum Engineer
Alaska Oi and Gas Conservation Commission
20f2
9/20/01 5:44 AM
1 C-1 02 Sundry - Change in Procedure
(
(
Subject: 1 C-1 02 Sundry .. Change in Procedure
Date: Wed, 19 Sep 2001 16:34:41 -0800
From: IISteve McKeeverll <smckeev@ppco.com>
To: tom_maunder@admin.state.ak.us
CC: "Sharon Allsup-Drake" <sallsup@ppco.com>
Hi Tom:
re: West Sak Multilateral Well 1 C-1 02/1 C-1 02L 1, Permits # 201-161,
201-172
Due to a delivery problem with a down hole sensor we would like
authorization for a completion procedure other than the one permitted for
the above well.
We had planned to run the ESP completion at the usual time, at the end of
the drilling phase, before the rig moves off. We are hoping that the AOGCC
will authorize us to suspend our operations on this well, move off, then
move back on in late November to run the ESP.
The attached file details the proposed changes in procedure, with a
schematic showing the welt as it would be "suspended".
If this alternative procedure is acceptable to the Commission, can you
please provide authorization via e-mail? Should you provide such
authorization we will follow up with a formal Application for Sundry
Approval, should you require it.
We are expecting to move off ot this well sometime early next week.
(See attached file: 10-1 02L 1 Sundry Procedure change.pdt)
Steve McKeever
Drilling Engineer
Phillips Alaska, Inc.
907.265.6826 office
907.265.1535 fax
907.275.0369 pager
smckeev@ppco.com
"It is better to keep your mouth shut and appear stupid than to open it and
remove all doubt."
- Mark Twain
_..m-._.m._.'._...-.,..~- "
~
Name: 1 C-1 02L 1 Sundry Procedure change.pdf
~1C-102L 1 Sundry Procedure change.pdf Type: Acrobat (applicalion/pdf)
. Encoding: base64
10f2
9/20/01 4:59 AM
(
t
Permitted Procedure for lC-l02
1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 161' RKB. Weld landing ring on conductor. Install
wellhead.
2. Move in / rig up Nabors 245e. Install Diverter / BOPE and function test same.
3. Spud and direction ally drill 9-7/8" hole to casing point at +/- 6410' MD /3794' TVD as per directional plan. Run MWD,
LWD and PWD tools as required for directional monitoring and data gathering.
4. Run and cement 7-5/8",29.7#, L-80, BTC Mod casing to surface. Displace cement with mud and perform stage job or
top job if required.
5. Note: Port collar to be run @ +/- 1000' MD.
6. Nipple down diverter, NU and test BOP's. Notify AOGCC 24 hrs before test.
7. PU 6-3/4" PDC Bit and directional BHA. RIH, clean out cement to top of float equipment, pressure test casing to 3000 psi
for 30 minutes and record results.
8. Drill out cement and between 20' and SO' of new hole. Perform FIT not to exceed 12.0 ppg EMW and record results
(ECD's estimated not to exceed 11.5 ppg)
9. Directionally drill 6-3/4" hole to TD at +/- 10585' MD /3,744' TVD as per directional plan.
10. POOH and lay down MWD, LWD and PWD tools.
11. RIH with 6-3/4" hole opener and ream entire open hole.
12. Circulate and condition hole to run liner. Displace mud with c;lean filtered kill weight brine and spot viscosified brine
across open hole.
13. RIH with casing scaper assembly to 7-5/8" shoe. Perform casing and drill pipe clean--up including Caustic SL Wash and
Acid Pickle. Displace casing with kill weight viscosified brine.
14. PU and run 4" Liner with excluder screen (run liner with 2-7/8" inner wash string).
15. Land liner, set liner top packer @ +/- 5944' MD / 36811 TVD and dIsplace viscosified brine with clean filtered brine. Spot
8% Formic Acid through the screens and allow acid to soak 6 hours. Displace acid with clean filtered brine.
16. POOH to liner top and displace well, above liner top packer, with clean filtered brine. Continue POOH and lay down 2-
7/8" inner wash string assembly.
Permitted Procédure for lC-l02Ll (with proposed changes in blue)
1. Run and set Baker WindowMasterTM whipstock, 30 degrees to left of high side.
2. Mill starting window in K-13 shale above the D-sand. POOH.
3. Polish and complete window with finishing mill and 2 watermelon miJIs.
4. Pick up 6" drilling assembly, RIH, and drill 20-50 feet of new hole.
5. Perform Formation Integrity Test to 12.0 ppg EMW.
6. Drill through shale to the D Sand heel. Change over to BaraDril'N drilling mud.
7. Continue to directionally drill to TD of D sand lateral at 10,571' MD /3,691' TVD. POOH.
8. POOH and lay down MWD, LWD and PWD tools.
9. RIH with 6" hole opener and ream entire open hole.
10. Circulate and condition hole to run liner. Displace mud with clean filtered kill weight brine and spot
viscosified brine across open hole. POOH and lay down hole opener assembly.
11. RIH with whipstock retrieval tool and casing scaper assembly to whipstock. Perform casing and drill pipe clean-up
including Caustic SL Wash and Acid Pickle. Displace casing with kill weight brine. Retrieve whipstock and POOH.
12. PU 4" Liner with flanged hook hanger, ECP's and excluder screen and 2~7/8" inner wash string.
13. RIH, until Hook Hanger is just above window. Run gyro tools to orient hook hanger to window and land hanger.
14. Release hanger running tool and place cup tool across each ECP and inflate with cement. Reverse out excess cement and
POOH.
15. Pick up lateral diverter tool and RIH and set in hook hanger.
16. RIH with cup tool assembly and spot 8% Formic Acid through the screens and allow acid to soak 6 hours. Displace acid
with clean filtered brine. POOH, laying down Drill pipe as needed.
-17-. ~1ake up lat£:fal diverter rctric-ving tool Jnd RIH on '1 1/2" completion tubing. Once Jt divcrter, run dummy ESP through
tul3iA§ str-iAg OR 'I.'ifcliAC. Reuie,,£: div£:Ftcr, GlAd POOH, staAdiA§ l3acl( tubing,
17. Make up lateral diverter retrieving tool on drill pipe. Retrieve diverter and POOH.
18. RIH with 4-1/2",12.6#, L-BO NSCTtubing to a depth of +/- 5880' MD.
19. Land Tubing, Lay down landing joint and set BPV.
20. Nipple down BOPE, Nipple up and test tree.
21. Rig up and freeze protect well by displaceing tubing and annulus to diesel to a depth of 2000' TVD..
22. Shut in well. Set BPV. RDMO Nabors 245e.
23. Rig up wireline and run Centrilift dummy ESP (3.833 OD) through tubing. Tag up at the minimum 1D in the
crossover at the bottom of the tubing string.
24. Move in and rig up Nabors 245e.
25. Pull BPV.
26. Rig up to circulate out freeze protection fluid with 8.9 ppg 3% KCI brine.
27. Install BPV. Nipple down tree and tree adapter flange. Nipple up 13-5/8" 5K BOP and test.
28. Screw in landing joint, back out lock down screws and pull hanger to floor. Ensure well is dead.
29. POOH standing back tubing in stands
30. Make up ESP and components as required and RIH. Run heat trace on tubing through permafrost zone.
31. Land tubing with ESP +/~ 60 feet above window. Install BPV, nipple down stack, nipple up and test tree. Pull BPV, Freeze
protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize.
32. Set BPV and move off.
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Well # 1C-102, AFE #AK0202
West Sak Multilateral Well
Planned Completion Schematic
Status at Rig Move Details
«; r~~~J~,~~~~;
T.. ~.8btt, Vek:o
Gray Gen II, API 13-618 -
5000 psi Flange Down x 4-
1/16"' 5000 SIudded Top,
wiIh Perldbdb::.
Tubing Hanger. 4-1Tr, Vek:o Gray wi
4.909" MCA Top Connection. 4-1rr l-80
NSCT Pup Joint Down
~d'" Holes blanked off
Back Pressa88 Valve installed
Nabors Rig 245 RKB @ 0'"
Easmgs: 561.606..18
NorIIW1gs: 5.968.813.50
Elevation: 101 11 AMSL
TuI*1g Head Assllmbly.
Vek:o Gray
(1) Joint Tubing
16- Conduckw:
+1- 158" 80
(x) Joints Taj)ing
Tubing String:
4-112",12.81,
L-80, NSCT
Port eou.:
+1-1'" MD '..1VD
(1) Cross 0lI8l', 4-112, 12..'" NSCT Box x r Une Pipe pin (481..t950)
Set at +1- 5880" lID , +1- 3G5r 1VD
7-518- Shoe:
+1- 6,518" lID ,
3,--1VD
------------
------------
--------.......---
--_._--------
------------
------------
--.-.---------,-
-----------
-----------
-----------
-----------
-----------
------------
-----------
Top of Window:
+I. 5,941" 80 I 3.680" 1VD
Top of Lower LaI8raI Uner:
+1- '045" 80 I 3,716" 1VD
0-8and lateralS- Open Hole TO:
+1- 11,&00" 18D I 3,691. 1W
------------
---------------
------------
------------
------------
------------
------------
-----------
-----------
-----------
-----------
-----------
-----------
-----------
B-&Ind I.aIøraI 6-314- Open Hale 1D:
10,mr MD I 3.753" 1VD
1G-102 Planned Comp/eIiJn SchemaIic
StaIus aI. Rig Mow DeIaíIs
prepared by Stew AfcKeever
September 18. 2001
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~VfA\VΠill)~ ~~fA\~[K\fA\ /
AIfASIiA. OIL AND GAS /
CONSERVATION COltDlISSION /
TONY KNOWLES, GOVERNOR
333 W. -¡n< AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Chuck Mallary
Drilling Engineering Supervisor
. Phillips, Alaska, Inc.
PO Box 100360
Anchorage AK 99510
Re:
Kuparuk River Unit 1C-I02L1
Phillips, Alaska, Inc.
Permit No: 201-172
Sur Loc: 1420' FNL, 600' FWL, SEC. 12, TIIN, R10E, UM
Btmhole Loc. 912' FSL, 2422' FEL, SEC. 11, T11N, R10E, UM
Dear Mr. Mallary:
Enclosed is the approved application for permit to drill the above referenced well.
The permit to drill does not exempt you from obtaining additional permits required by law from
other governmental agencies, and does not authorize conducting drilling operations until all other
required permitting determinations are made.
The permit is for a new wellbore segment of existing well KRU 1 C-l 02, Permit No, 201-161,
API No. 029-23037. Production should continue to be reported as a function of the original API
number stated above.
Annular disposal has not been requested as part of the Permit to Drill application for 1 C-1 02L1.
Please note that any disposal of fluids generated from this drilling operation which are pumped
down the surface/production casing annulus of a well approved for annular disposal on 1 C Pad
must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit
to drill does not authorize disposal of drilling waste in a volume greater than 35,000 baae1s
through the annular space of a single well or to use that well for disposal purposes for a period
longer than one year.
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Pennit No: 201-172
August 22, 2001
Page 2 of2
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035.
Sufficient notice (approximately 24 hours) must be given to allow a representative of the
Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given
by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607.
BY ORDER OF THE COMMISSION
DATED this 22nd day of August, 2001
jjc/EnClosures
cc:
Department ofFish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
9. Approximate spud date
August27,2001
14. Number of acres in property
2560
17. Anticipated pressure (see 20 AAC 25.035 (e)(2))
Maximum surface 1311 psig At total depth (TVD) 1723 psig
Settin De th
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STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
1 a. Type of work: Drill 0 Redrill 0
Re-entry 0 Deepen 0
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P.O. Box 100360 Anchorage, AK 99510-0360
4. Location of well at surface
1420' FNL, 600' FWL, Sec. 12, T11N, R1OE, UM
At top of productive Interval
152' FSL,2374'FEL,Sec.2, T11N,R10E, UM
At total depth
912' FSL, 2422' FEL, Sec. 11, T11N, R10E, UM
12. Distance to nearest property line 13. Distance to nearest well
912' @ TD feet N/A
16. To be completed for deviated wells
Kickoff depth: 5882' MD
18. Casing program
size
1b. Type of well. Exploratory 0 Stratigraphic Test 0
Service 0 Development Gas 0 Single Zone 0
5. Datum elevation (DF or KB)
RKB41 feet
6. Property Designation
ADL 25649 ALK 467
7. Unit or property Name
Kuparuk River Unit
8. Well number
1 C-102L 1
feet
Maximum hole angle
91 0
Hole
Bottom
TVD
Casln
MD
9.875"
41'
5852'
6410'
10571'
7.625"
L-80
L-80
BTC Mod
HSLHT
6369'
4719'
29.7#
9.5#
41'
3669'
6"
4"
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total Depth:
Plugs (measured)
measured
true vertical
feet
feet
Effective Depth:
Junk (measured)
measured
true vertical
feet
feet
Casing
Conductor
Surface
Intermediate
Production
Liner
Length
Size Cemented
Measured depth
Perforation depth:
measured
true vertical
4rc0
Development Oil 0
Multiple Zone 0
10. Field and Pool
Kuparuk River Field
West Sa!< Oil Pool
11. Type Bond (see 20 AAC 25.0251)
Statewide
Number
#5952 180
Amou nt
$200,000
15. Proposed depth (MD and TVD)
10571 ' MD 13691 ' TVD
3794'
3691'
open hole
screen
True Vertical depth
Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0
0 Time vs depth plot DRefractlon analysis 0 Seabed report 0 20 AAC 25.050 requirements 0
e 01 s true and co re t the best of my knowledge Questions? Call Scott Lowry 265-686~
Date It!
20. Attachments
Signed
Title: Drilling Engineering SupeNisor
Permit Number API numbe
:20/- /72.. 50-0 .:zSð6 ;?-6ð
Conditions of approval Samples required 0 ~ No
Hydrogen sulfide measures 0 Yes ~ No
Required working pressure for BOPE D2M; 0 3M;
Other:
Mud log required
Directional survey required
0 5M; 0 10M;D
See cover letter
for other requirements
0 Yes No
J8I Yes 0 No
7:,(:f.:)f:) \'~, ~,,, \ Y¥\ \\ "" '3~ Y ~--\--
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ORIGINAL SIGNED
D T a lor BY
Commissioner
by order of
Form 10-401 Rev. 12/1/85.
Submit in triplicate
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'Application for Permit to Drill, Well 1 C-1 02
Revision No.1
Saved: 13-Aug-01
Permit It - West Sak Well #1 C-1 02 L 1
Application for Permit to Drill Document
MoximizE
Well VQIU~
Table of Contents
1. Well Name.............. .................................. ... ...... ........................................................ 2
Requirements of 20 AAC 25.005 (f)........................................................................................................ 2
2. Location Sum mary ............................................................. ......... .............................2
Requirements of 20 AAC 25. 005( c)(2) ........... ........................................................................................ 2
Requirements of 20 AAC 25.050(b).. ......... ......... .... ............. .... ......... ............ ........................ ..... ..., .... .....3
3. Blowout Prevention Equipment Information ......................................................... 3
Requirements of 20 AAC 25.005(c)(3) .".",,,.,,,,,,,,,,,,,,,,,,,.,,,,.,,,,,,,,,,,,,,,,..,,,,.,,,,,,,,,,,,.,,.,,.,,,,..,,,,,,,,.,.,,,,, 3
4. Dri II i ng Hazards Information................................................................................... 3
Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3
5. Procedure for Conducting Formation Integrity Tests ........................................... 3
Requirements of 20 AAC 25.005 (c)(5) ........................................................................................,......... 3
6. Casing and Cementing Program ........................... ..................................................4
Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4
7. Diverter System Information .............. ....... ............................. ................................. 4
Requirements of 20 AAC 25.005(c)(7) ...................................................................................................4
8. Dri II i ng FI u id Program............................................................................................. 4
Requirements of 20 AAC 25. 005( c)(B) ................................................................................................... 4
9. Abnormally Pressured Formation Information ...................................................... 5
Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5
1 O. Seism ic Analysis............................................ ............... ........................................... 5
Requirements of 20 AAC 25.005 (c)(1 0) ...."'."".".....'.'..."...."..".....".....".....'.'.'.... .................. ............5
11. Seabed Condition Analysis .....................................................................................5
Requirements of 20 AAC 25.005 (c)(11) ................................................................................................5
12. Evidence of Bond i ng................................................................................................ 5
Requirements of 20 AAC 25.005 (c)(12) ....................................,...........................................................5
1C-102L 1 PERMIT IT ver.1.doc
0 RIG ¡ IV ~r/:ff-~¿:-~;
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Application for Permit to Drill, Well 1 C-1 02
Revision NO.1
Saved: 13-Aug-0 1
13. Proposed Dri Iii ng Program ..... ............. ...... .................... ..........................................5
Requirements of 20 AAC 25.005 (c){13) .......... .............................. ........................................ ........... .....5
14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6
Requirements of 20 AAC 25.005 (c){14) ................................................................................................6
15. Attach ments .. ....................................... ...... .............................................................. 7
Attachment 1 Directional Plan (6 pages) ............................................................................................... 7
Attachment 2 Drilling Hazards Summary (1 page) ................................................................................ 7
Attachment 3 Well Schematics (2 pages)...... ............, ....... ...... ...... ........ .......... ..................... ......... ........ 7
1. Well Name
Requirements of 20 AAC 25.005 (f)
Each well must be identified by a unique name designated by the operator and a unique API number as..signed by the commission
under 20 AAC 25.040(17). For a well wIth multiple well 17ranche~ each brandl must similarly be ident/fìed by a unique name and API
number by adding a suffìx to the name designated for the well by the operator and to the number assigned to the well by the
commission.
The well for which this Application is submitted will be designated as 1C-102 L1.
2. Location Summary
Requirements of 20 AAC 25.005(c){2)
An application for a Permit tv Dnll must be accompanied by each of the following items¡ except fÒr an item already on file with the
commission and identified in the appliœtion:
(2) a plat idenDfying the property and the properfy:s' owners- and showing
(A)t17e coordinate5- of the proposed location of the well at the surface" at the top of each ot?jectille formation, and at tvtal depth,
rererenced to governmental section lines:
(B) the coordinates of'the proposed location of the well at the surféce, referenced to the state plane coordinate system for tflis
state as maintained by the National Geodetic Swvey in the National Oceanic and Atmosplm!ic Administrt~tiol7,,'
(C) the prop°:,è?d depth or the well at the top of each objective formation and at total depth;
Location at Surface I 1420' FNL, 600' FWL, Section 12, T11N, R10E, UM
NGS Coordinates I RKB Elevation I 102.0' AMSL
Northings: 5,968,813.187 Eastings: 561,605.104 I Pad Elevation I 60.8' AMSL
Location at Top of
Productive Interval
West Sak "D" Sand
NGS Coordinates
Northings: 5,970,361
152' FSL, 2374' FEL, Section 2, T11N, Rl0E, UM
Eastings: 558,619
6046
3733
3631
Location at Total De th
NGS Coordinates
Northings: 5,965,842 Eastings: 558,610
UM
10571
3691
3589
and
(0) other information required by 20 MC 25".050(b);
1C-102L 1 PERMIT IT ver.1.doc
Page 2 of 7
(J H I u J IV A t"nted: 13-Aug-OI
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Application for Permit to Drill, Well 1 C-1 02
Revision No.1
Saved: 13-Aug-01
Requirements of 20 AAC 25. 050 (b)
If a well is to be intentionally deviatect the application for a Permit to Drill (Form 10-401) must
(/) include a pla0 drawn to a suitable scale/ showing tl7e path of the proposed wellbore/ includli7g a/I adjacent wel/bores within 200
feet of any portion of the proposed well/'
Please see Attachment 1: Directional Plan
and
(2) for all wells within 200 feet of the proposed wellbore
(A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public records,
and show tl7at each named operator has been furnished a copy of the application by certIfied ma/~' or
(8) state that the applicant I~<; the only affected owner.
The Applicant is the only affected owner.
3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
An application for a Permit to Drill must be accompanied by each of the following Items, except for an Item already 017 file with the
commis:;ion and Identified in the application:
(3) a diagram and description of the blowout prevention equipment' (BOPE) as required by 20 AAC 25J}35~ 20 AAC 25.036, or 20
MC 25. 03~ as applicable;
An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete welllC-l02 L1. Please see
"Diagram and Description of the Blowout Prevention Equipment for Nabors Rig 245e", placed on file with
the Commission.
4. Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
An application for a PermIt to Drill must be accompanied by each of the following item'i/ except for an item already 017 tHe with the
commis:<;ion and identified in the application:
(4) information on drilling hazard5~ including
(A) the maximum downhole pressure that may be encounterect aiteria used to determine it~ and maxirnum potential surface
pres:''';"ll!'e basë:!d on a methane gradient;
The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.43 to 0.46 psi/ft,
or 8.2 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data
from the nearby WS1-0l well.
The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a
methane gradient (0.11) and the vertical depth of the expected base of the West Sak formation is 1311
psi, calculated thusly:
MPSP =(3746 ft)(0.46 - 0.11 psi/ft)
=1311 psi
(B) data on potential gas zones/
The well bore is not expected to penetrate any gas zones.
t;']nd
(C) data concerning potential caœies of hole problems such as abnormally geo.pressllred strata, lost circulation zones, and zones
ihat have a propensity for difFerential $tic*ing,"
Please see Attachment 2: Drilling Hazards Summary.
5. Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(5)
An application for a Pé'l7l71t to Dnll must be accompanied by each ot'the following Item5~ exæpt for c1n item already on file with the
commission and identified in the application:
(5) a de!:>ì::ription of the procedure for conducting formation integrity tests, as requked LInder 20 AAC 25. 030(t)/.
lC-l02 Ll will be completed with 7-5/8" surface casing landed in the West Sak B-Sand, which was
permitted as 1C-l02. A whipstock will be set to mill a window in the 7 5/8" casing in the K-13 shale
1C-102L 1 PERMIT IT ver.1.doc
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Application for Permit to Drill, Well 1 C-1 02
Revision NO.1
Saved: 13-Aug-01
above the West Sak D-Sand. A formation integrity test will be performed in accordance with the
"Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission.
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An application for a PermIt to Drill must be accompanied by each of the following Items, except for an item already on tile with the
commission and identitied in the application:
(6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted lIi7er, pre-
perforated liner, or screen to be fi7stalled;
Casing and Cementing Program
Hole Top Btm
CsgfTbg Size Weight Length MOfTVO MOfTVO
00 (in) (in) (Ibltt) Grade Connection (tt) (tt1 (ft) Cement Program
16 24 62.5 H-40 Welded 120 41/41 161 / 161 Cemented to
surface with
225 cf
ArcticSet 1
7-5/8 9-7/8 29.7 L-80 BTCM 6369 41/41 6410/3794 Cemented to
Surface with
650 sx ASLite
Lead, 240 sx
Class G Tail
4 6" 9.5 L-80 HSLHT 4719 5852/ 3669 10571/3691 Screens -
screen Upper Inflate ECP
Lateral with cement
7. Diverter System Information
Requirements of 20 AAC 25.005(c)(7)
An application f'Or a Permit to Dnll must' be accompanied by each of the (allowing item5~ except fÓr an item already on file with the
commi.s:sion and identitìecl in the application:
(7) a diagram and desaiption of the dive/tel' system as required by 20 AAC 25. 015, unk.'ss this requirement is waived by the
commission under 20 AAC 25.035(17)(2);
A diverter system will not be used while drilling the West Sak "D" lateral.
8. Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(B)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commi.%ìÒn and Identtfied in the appliC/;¡t/ol7:
(8) a drilling flUid prograrn including a diagram and de:.-,Y:rfption of/he drilling fluid system, as requked by 20 AAC 25",033;
Drilling will be done with a BaradrilN mud system having the following properties over the listed intervals:
Sidtrack interval fK-13 shale only) D sand lateral
Initial Value Final Value Initial Value Final Value
Density (ppg) 9.0-9.1 9.0-9.1 8.9-9.0 8.9-9.0
Funnel Viscosity (seconds) 40-55 40-55 45-60 45-60
Yield Point 20-27 20-27 18-25 18-25
{cP}
Plastic Viscostiy (lb/l00 sf) 11-19 11-19 8-14 8-14
Tau 0 4-7 4-7 4-7 4-7
Chlorides 13-15K 13-15K 13-15K 13-15K
pH 8-9 8-9 8-8.5 8-8.5
1C-102L 1 PERMIT IT ver.1.doc
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Application for Permit to Drill, Well 1 C-1 02
Revision No.1
Saved: 13-Aug-01
API filtrate <6 <6 <6 <6
**HTHP filtrate <10 <10 <10 <10
MDT <11 <11 <2.5 <2.5
***Solids ppb <12 <12 <12 <12
* * HTHP to be run at 80° F
*** The drilled LGS
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
This drilling fluid system of Nabors Rig 245e consists of: (3) Continental Emsco FB-1600 Mud Pumps,
Steel Mud pits with 1100 barrel capacity, Pill Pit, Trip Tank, (3) Derrick Flo-line Shale Shakers (rated at
600 gpm), Brandt Model SRS-2 Desander, Derrick Model 58S Mud Cleaner, (2) Alpha-Laval Model 418-VT-
5 Centrifuges, Degassers, PVT System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid
Agitators.
Please see "Diagram of Mud System, Nabors Rig 245e", placed on file with the Commission.
9. Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An application for a Permit to Drill must be accompanied by each of the following ttems~ except tor an item already on tYe wIlh the
commission and Identified in the application:
(9) for an exploratory or stratigraphic test well, a tabulation !:t-etting out the depths of predicted abnormally g¿)o-pre!;t"sured stmta as
required by 20 AAC 25.033(f)/
Not applicable: Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
An application tor a PermIt to Dn/I must be accompanied by each of the fÓllowing Item.'i¡ except fÓr an Item a/ready 0/7 tHe with the
commission and idenftfied in the application:
(10) fÓr an exploratory or strat~qrðphic test well, a sei!:>ì77ic refraction or reflection analysì:<i as required by 20 AAC 25,061(a)/
Not applicable: Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
An application far a Permlt'to Dnll must' be accompanied by each of the tollowing item5~ except for an item already on file with the
commission and iden17lìed in the application:
(11) for a well drilled from an off¿'7¡Ore platforrn mobIle bottom-founded structure/ jack-up fig, or floating drilling vessel an analysis
of :;;ì.:;abed conditions as required by 20 MC 25. 061 (b)/
Not applicable: Application is not for an offshore well.
12. Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
An application for a Permit to Drill must be accompanied by each of the fol/owing item::,-:, except for an item already 0/7 file with the
commiss1on and identifted in the applicatkm:
(12) evkJenΠshowing that the requirements of 20 AAC 25'.025" {BomJinq}have been met;
Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
An application for a Permit to On/I must be aa~ompanied by each of the following items~ except for an item already on ¡lIe w/lh the
commission and Identified in the application:
The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematics. This
procedure will begin upon completion of the lower lateral, lC-l02.
1. Run and set Baker WindowMasterTM whipstock, 30 degrees to left of high side.
2. Mill starting window in K-13 shale above the D-sand. POOH.
1C-102L 1 PERMIT IT ver.1.doc
A';: t Page 5 of 7
V lï Î \"11 i yi ,,';" rinted: 13-Aug-01
I{
(
Application for Permit to Drill, Well 1 C-1 02
Revision NO.1
Saved: 13-Aug-01
3. Polish and complete window with finishing mill and 2 watermelon mills.
4. Pick up 6" drilling assembly, RIH, and drill 20-50 feet of new hole.
5. Perform Formation Integrity Test to 12.0 ppg EMW.
6. Drill through shale to the D Sand heel. Change over to BaraDril'N drilling mud.
7. Continue to directionally drill to TD of D sand lateral at 10,571' MD / 3,691' 1VD. POOH.
8. POOH and lay down MWD, LWD and PWD tools.
9. RIH with 6" hole opener and ream entire open hole.
10. Circulate and condition hole to run liner. Displace mud with clean filtered kill weight brine and spot
viscosified brine across open hole. POOH and lay down hole opener assembly.
11. RIH with whipstock retrieval tool and casing scaper assembly to whipstock. Perform casing and drill
pipe clean-up including Caustic SL Wash and Acid Pickle. Displace casing with kill weight brine. Retrieve
whipstock and POOH.
12. PU 4" Liner with flanged hook hanger, ECP's and excluder screen and 2-7/8" inner wash string.
13. RIH, until Hook Hanger is just above window. Run gyro tools to orient hook hanger to window and land
hanger.
14. Release hanger running tool and place cup tool across each ECP and inflate with cement. Reverse out
excess cement and POOH.
15. Pick up lateral diverter tool and RIH and set in hook hanger.
16. RIH with cup tool assembly and spot 8% Formic Acid through the screens and allow acid to soak 6 hours.
Displace acid with clean filtered brine. POOH, laying down Drill pipe as needed.
17. Make up lateral diverter retrieving tool and RIH on 4-1/2" completion tubing. Once at diverter, run
dummy ESP through tubing string on wireline. Retrieve diverter, and POOH, standing back tubing.
18. Make up ESP and components as required and RIH. Run heat trace on tubing through permafrost zone.
19. Land tubing with ESP +/- 60 feet above window. Install BPV, nipple down stack, nipple up and test tree.
Pull BPV. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and
allowing to equalize.
20. Set BPV and move off.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application for a Permit to Drill mustc be accompanied by each olll7e lollowirl9 items¡ except lor an item already on f¡le wIth the
commission and Identified in the application:
(14) a genert~1 descnþtion of how the operator plans to d/'ij)ose of dnlling mud and cuttings and a statement of whether the
operator intends to request authorization under 20 AAC 2.5.080 for a/7 annular disposal operation li7 the well.;
Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids
into a permitted annulus on lC Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings
generated will be disposed of either down a permitted annulus on lC Pad or hauled to the Prudhoe Bay
Grind and Inject Facility for temporary storage and eventual processing for injection down an approved
disposal well.
Phillips Alaska does not intend to request authorization for the use of this well for annular disposal
operations.
ORIG 1,C-102L1 PERMITITver.1.doc
INAL Page6of7
Printed: 13-Aug-01
(,
(
Application for Permit to Drill, We1l1C-102
Revision NO.1
Saved: 13-Aug-O 1
15. Attachments
Attachment 1 Directional Plan
Attachment 2 Drilling Hazards Summary
Attachment 3 Well Schematics
1C-102L 1 PERMIT IT ver.1.doc
; Page 7 of 7
II f. , ~. ~ d wi i~~ l:inted: 13-Aug-01
2760
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4370
Phillips Alaska, Inc.
Structure: Pod 1 C
Well: 102(8)
Field: Kuporuk River Unit
Location: North Slope,
Created by f;nch For: S McKeever
Dote plotted: 17-Jul-2001
Plot Reference is 102 BLot v.2.
Coordinates ore in feei reference slot 1102.
Vertical Depths are re~~ËRKB 102'
6AIffil--
HUGlES
--
ø
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C)C)
,
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¡ ~C)'~(Q
t ~"C)~ <Q e, HORIZONTAL ANGLE
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". ~~' 0~c{" oèJ¡<Q:}~èt ~if OV 90. 7 1 DE G ~
. -<-.. oq R V q: (<,\::;_0 (\ \«) «
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~/I,' Û)'t- '...., +=-<-.. oq e,~ e, \~' ,,::,0 -<-.." <:) <:) /
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-<-..oq è)\ vO ~' ",. <) /
0e, \'b ~ ,<:- '"
<ý <Q /I, ~ B LATERAL
TARGET ANGLE
91.26 DEG
------.
2300
2070
1840
1610
1380
2760
2990
32
1150
920
2300
2530
690
460
230
0
230
460
690
920
1150
1380
1610
1840
2070
Vertical Section (feet) ->
Azimuth 180.00 with reference 0.00 N, 0.00 E from slot # 102
(,'
C,,,,,,.. "" ';ne" For: S McKeever
DoI~ p~OH('d : 11-Jul..2D01
Plot Rr!('fenco ;, 102 D LOt w.2.
C.oofd''''ale~ 0'1: ;" Ie-c-t tcderel'lC:c ,10: '10.2.
TruCl' VNticol DC'Plh. cr. 'IIIerenee RKB 102' (N-24~E).
E..
BAKER
HUGttSS
INTEl)
3500 3250 3000
(
Structure: Pod 1 C
Phillips Alaska, Inc.
Well: 102(D)
Field: Kuparuk River Unil Location: Norlh Slope, Alaska
2750
2500
2250
.Top Ugnu C
Top Ugnu B
Top Ugnu A
EOC ~'" ~.
K-13 rv"-"/K13
Begin Turn/Build rv~' ,,-Top Whipstock Face
Top W Sak D " K~'þsJM~lh~~;~cte~t~e
TopWSakD
EOC
C
B
TGT B Heel/EOC
7 5/8 Casing
B LATERAL
TOP W SAK D LOCATION:
182' FSL, 2365' FEL
SEC. 2, T11 N, R10E
B SAND LOCATION:
36' FNL, 2433' FEL
SEC. 11, T11N, R10E
In!. Tgt #5
B LATERAL
HEEL TARGET LOCATION:
193' FNL, 2447' FEL
SEC. 11, T11N, R10E
In!. Tgt #8
B LATERAL
TO LOCATION:
912' FSL, 2747' FEL
SEC. 11, T11N, R10E
TD - Csg pt TD - Csg pt
102(B) 102(0)
..
..
D LATERAL
TOP W SAK D LOCATION:
152' FSL, 2374' FEL
SEC. 2, T11N, R10E
N
..0:
l'-
0>
0)
s:
D LATERAL
HEEL TARGET LOCATION:
193' FNL, 2422' FEL
SEC. 11, T11 N, R10E
D LATERAL
TO LOCATION:
912' FSL, 2422' FEL
SEC. 11, T11N, R10E
<- West (feet)
2000
1750
1500
1000
1250
'" Beg Turn/Build
\Tap K-15
~
, '"
, '<:9-
\ U'
\ ..,
, ~
,
,
\
"
750
500
250
\
'.. Base Permafrost
\,
\, >it EOC
Beg 6/100 Bld'>it..¡¡¡'II KOP
Begin Turn/Build '?o1>
r¡.""fò
SURFACE LOCATION:
1420' FNL, 600' FWL
SEC. 12, T11N, R10E
290.00 AZIMUTH
3283' (TO 7 5/8" CSG PT)
".Plane of Proposal".
~
~i]
TRUE
250
2250
2000
1750
1500
1250
1000
750
500
250
tf)
0
c:
-+-
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-+.
CD
500 CD
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I
750 V
1000
1250
1500
1750
2000
2250
2500
2750
3000
250
OHI (iI/VA L
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Phillips Alaska, Inc.
Pad lC
102(D)
slot #102
Kuparuk River Unit
North Slope, Alaska
PRO P 0 S ALL I S TIN G
by
Baker Hughes INTEQ
Your ref: 102 D Lat v.2
Our ref: prop4395
License:
Date printed: 17-Jul-2001
Date created: 15-Jan-2001
Last revised: 17-Jul-2001
Field is centred on n70 16 18.576,w150 5 56.536
Structure is centred on n70 19 45.173,w149 30 19.124
Slot location is n70 19 31.207,w149 30 1.611
Slot Grid coordinates are N 5968813.187, E 561605.104
Slot local coordinates are 1420.00 S 600.00 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ORIGINAL
\ (
Phillips Alaska, Inc. PROP08AL LI8TING Page 1
Pad 1C,102(D) Your ref : 102 D Lat v.2
Kuparuk River Unit, North 8lope, Alaska Last revised : 17-Jul-2001
Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D 8 G E 0 G R A PHI C
Depth Degrees Degrees Depth COO R D I N ATE 8 Easting Northing COO R D I N ATE 8
0.00 0.00 236.00 0.00 O.OON O.OOE 561605.10 5968813 .19 n70 19 31. 21 w149 30 01.61
250.00 0.00 236.00 250.00 O.OON O.OOE 561605.10 5968813 .19 n70 19 31. 21 w149 30 01.61
350.00 3.00 236.00 349.95 1. 468 2.17W 561602.95 5968811.71 n70 19 31.19 w149 30 01.67
450.00 6.00 236.00 449.63 5.858 8.67W 561596.48 5968807.27 n70 19 31.15 w149 30 01.86
550.00 9.00 236.00 548.77 13 . 158 19.49W 561585.72 5968799.88 n70 19 31.08 w149 30 02.18
600.00 9.36 245.13 598.13 17.058 26.42W 561578.82 5968795.93 n70 19 31.04 w149 30 02.38
700.00 10.68 260.67 696.62 21. 978 42.94W 561562.35 5968790.87 n70 19 30.99 w149 30 02.86
800.00 12.58 272.21 794.58 23.058 62.97W 561542.33 5968789.63 n70 19 30.98 w149 30 03.45
900.00 14.84 280.53 891.73 20.298 86.45W 561518.83 5968792.20 n70 19 31. 01 w149 30 04.13
1000.00 17.32 286.60 987.82 13 . 698 113. 32W 561491.91 5968798.57 n70 19 31.07 w149 30 04.92
1072.00 19.20 290.00 1056.19 6.588 134. 72W 561470.46 5968805.51 n70 19 31.14 w149 30 05.54
1100.00 20.51 293.08 1082.53 3.088 143.56W 561461.59 5968808.94 n70 19 31.18 w149 30 05.80
1200.00 25.54 301.50 1174.55 15.07N 178. 09W 561426.91 5968826.80 n70 19 31.36 w149 30 06.81
1300.00 30.90 307.22 1262.65 41. 89N 216.96W 561387.83 5968853.31 n70 19 31.62 w149 30 07.94
1400.00 36.45 311.38 1345.84 77.09N 259.74W 561344.77 5968888.16 n70 19 31.97 w149 30 09.19
1500.00 42.10 314.56 1423.23 120.29N 305.95W 561298.21 5968930.97 n70 19 32.39 w149 30 10.54
1600.00 47.83 317.11 1493.96 171.01N 355.10W 561248.66 5968981.29 n70 19 32.89 w149 30 11.98
1700.00 53.60 319.23 1557.27 228.69N 406.64W 561196.65 5969038.54 n70 19 33.46 w149 30 13.48
1800.00 59.40 321.06 1612.44 292.70N 460.02W 561142.77 5969102.11 n70 19 34.09 w149 30 15.04
1847.08 62.14 321.85 1635.43 324.83N 485.61W 561116.92 5969134.03 n70 19 34.40 w149 30 15.78
2000.00 62.14 321.85 1706.89 431.15N 569.13W 561032.54 5969239.65 n70 19 35.45 w149 30 18.22
2500.00 62.14 321.85 1940.55 778. 76N 842.20W 560756.68 5969585.00 n70 19 38.87 w149 30 26.19
3000.00 62.14 321.85 2174.20 1126. 38N 1115.28W 560480.81 5969930.35 n70 19 42.29 w149 30 34.17
3500.00 62.14 321.85 2407.86 1473.99N 1388. 35W 560204.95 5970275.70 n70 19 45.70 w149 30 42.14
4000.00 62.14 321.85 2641.52 1821.60N 1661.42W 559929.09 5970621.05 n70 19 49.12 w149 30 50.11
4130.78 62.14 321.85 2702.63 1912.53N 1732. 85W 559856.93 5970711.38 n70 19 50.02 w149 30 52.20
4200.00 60.13 317.70 2736.06 1958.81N 1771.97W 559817.44 5970757.34 n70 19 50.47 w149 30 53.34
4300.00 57.46 311.41 2787.90 2018.81N 1832.82W 559756.11 5970816.84 n70 19 51.06 w149 30 55.12
4400.00 55.13 304.76 2843.43 2070.13N 1898.19W 559690.33 5970867.62 n70 19 51.57 w149 30 57.03
4500.00 53.18 297.76 2902.04 2112. 20N 1967.37W 559620.82 5970909.13 n70 19 51.98 w149 30 59.05
4600.00 51.66 290.44 2963.08 2144.57N 2039.60W 559548.33 5970940.90 n70 19 52.30 w149 31 01.16
4700.00 50.61 282.85 3025.89 2166.88N 2114. 09W 559473.67 5970962.60 n70 19 52.52 w149 31 03.33
4800.00 50.06 275.08 3089.78 2178.87N 2190.02W 559397.66 5970973.98 n70 19 52.63 w149 31 05.55
4900.00 50.04 267.25 3154.04 2180.44N 2266.56W 559321.12 5970974.92 n70 19 52.65 w149 31 07.78
5000.00 50.55 259.48 3217.98 2171.54N 2342.87W 559244.89 5970965.40 n70 19 52.56 w149 31 10.01
5100.00 51. 56 251.87 3280.90 2152.29N 2418.11W 559169.81 5970945.54 n70 19 52.37 w149 31 12.21
5200.00 53.05 244.52 3342.10 2122.89N 2491.47W 559096.70 5970915.55 n70 19 52.08 w149 31 14.35
5300.00 54.97 237.50 3400.91 2083.67N 2562.13W 559026.36 5970875.76 n70 19 51.70 w149 31 16.41
5400.00 57.27 230.82 3456.70 2035.05N 2629.33W 558959.57 5970826.60 n70 19 51.22 w149 31 18.37
5500.00 59.92 224.51 3508.84 1977.57N 2692. 32W 558897.05 5970768.62 n70 19 50.65 w149 31 20.21
5600.00 62.84 218.54 3556.77 1911.86N 2750.42W 558839.49 5970702.45 n70 19 50.01 w149 31 21. 91
5622.65 63.54 217.23 3566.98 1895. 91N 2762.84W 558827.21 5970686.39 n70 19 49.85 w149 31 22.27
5779.79 63.54 217.23 3637.00 1783. 90N 2847.96W 558743.01 5970573.71 n70 19 48.75 w149 31 24.76
5851.61 63.54 217.23 3669.00 1732. 71N 2886.86W 558704.53 5970522.21 n70 19 48.25 w149 31 25.89
5863.61 65.20 216.18 3674.19 1724. 04N 2893.33W 558698.14 5970513.48 n70 19 48.16 w149 31 26.08
5881.61 65.20 216.18 3681.74 1710. 85N 2902.97W 558688.60 5970500.22 n70 19 48.03 w149 31 26.36
5900.00 66.62 214.11 3689.25 1697.12N 2912.63W 558679.05 5970486.41 n70 19 47.89 w149 31 26.64
6000.00 74.77 203.55 3722.36 1614.55N 2957.84W 558634.52 5970403.49 n70 19 47.08 w149 31 27.96
6046.38 78.73 198.96 3733.00 1572. 49N 2974.19W 558618.52 5970361.30 n70 19 46.67 w149 31 28.44
6100.00 83.38 193.80 3741.34 1521. 70N 2989.10W 558604.02 5970310.40 n70 19 46.17 w149 31 28.87
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #102 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level).
Bottom hole distance is 4219.10 on azimuth 225.70 degrees from wellhead.
Total Dogleg for wellpath is 207.37 degrees.
Vertical section is from N 0.00 E 0.00 on azimuth 180.00 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
(fffl1ß/ N A L
( ~,
Phillips Alaska, Inc. PROP08AL LI8TING Page 2
Pad 1C,102(D) Your ref : 102 D Lat v.2
Kuparuk River Unit,North 8lope, Alaska Last revised : 17-Jul-2001
Measured Inclin Azimuth True Vert R E C T A N G U L A R G RID COO R D 8 G E 0 G R A PHI C
Depth Degrees Degrees Depth COO R DIN A T E 8 Easting Northing COO R D I N ATE 8
6183.46 90.71 185.95 3745.65 1439.70N 3003.36W 558590.43 5970228.29 n70 19 45.36 w149 31 29.29
6321.66 90.71 185.95 3743.93 1302.26N 3017.67W 558577.24 5970090.75 n70 19 44.01 w149 31 29.71
6396.32 90.71 179.97 3743.00 1227.74N 3021. 52W 558573.99 5970016.21 n70 19 43.28 w149 31 29.82
6500.00 90.71 179.97 3741.71 1124. 07N 3021.47W 558574.89 5969912.55 n70 19 42.26 w149 31 29.81
7000.00 90.71 179.97 3735.48 624.11N 3021. 22W 558579.20 5969412.65 n70 19 37.34 w149 31 29.80
7500.00 90.71 179.97 3729.25 124.15N 3020.97W 558583.51 5968912.76 n70 19 32.42 w149 31 29.79
8000.00 90.71 179.97 3723.03 375.828 3020. 72W 558587.82 5968412.86 n70 19 27.51 w149 31 29.78
8500.00 90.71 179.97 3716.80 875.788 3020.48W 558592 .14 5967912.97 n70 19 22.59 w149 31 29.77
9000.00 90.71 179.97 3710.57 1375.748 3020.23W 558596.45 5967413.07 n70 19 17.67 w149 31 29.76
9500.00 90.71 179.97 3704.34 1875.708 3019.98W 558600.76 5966913 .18 n70 19 12.76 w149 31 29.74
10000.00 90.71 179.97 3698.11 2375.668 3019.73W 558605.07 5966413.29 n70 19 07.84 w149 31 29.73
10500.00 90.71 179.97 3691.89 2875.628 3019.49W 558609.38 5965913.39 n70 19 02.92 w149 31 29.72
10571.20 90.71 179.97 3691.00 2946.828 3019.45W 558610.00 5965842.20 n70 19 02.22 w149 31 29.72
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #102 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level).
Bottom hole distance is 4219.10 on azimuth 225.70 degrees from wellhead.
Total Dogleg for wellpath is 207.37 degrees.
Vertical section is from N 0.00 E 0.00 on azimuth 180.00 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ORIGINAL
(
~,
Phillips Alaska, Inc.
Pad 1C,102(D)
Kuparuk River Unit,North Slope, Alaska
PROPOSAL LISTING Page 3
Your ref: 102 D Lat v.2
Last revised: 17-Jul-2001
Comments in we11path
--------------------
--------------------
MD
TVD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
5779.79 3637.00 1783.90N 2847.96W K13
5851.61 3669.00 1732. 71N 2886.86W Top Whipstock Face
5863.61 3674.19 1724. 04N 2893.33W Base Whipstock Face
5881.61 3681.74 1710 . 85N 2902.97W KOP/Mill Bury Depth
6046.38 3733.00 1572.49N 2974.19W Top W Sak D
6183.46 3745.65 1439.70N 3003.36W EOC
6321.66 3743.93 1302.26N 3017.67W Begin Turn
6396.32 3743.00 1227.74N 3021.52W ws 1C-102 D-HEEL RVSD 22JUN01
10571.20 3691.00 2946.82S 3019.45W WS 1C-102 D-TOE RVSD 22JUN01
Casing positions in string 'A'
------------------------------
------------------------------
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
O.OON
O.OOE 6410.27 3742.83
1213.79N
3021.51W 7 5/8" Casing
Targets associated with this wellpath
-------------------------------------
-------------------------------------
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
-----------------------------------------------------------------------------------------------------------
WS lC-102 D-HEEL RVS
WS 1C-102 D-TOE RVSD
3743.00
3691.00
1227.74N
2946.82S
3021.52W 15-Jan-2001
3019.45W 15-Jan-2001
ORIGINAL
(
(
lC-l02 Ll Drilling Hazards Summary
(SEE WELL PLAN FOR DETAILED DISCUSSION OF THESE RISKS)
6" 0 en Hole 4" Liner Interval
Hazard
Abnormal Reservoir
Pressure
Stuck Pi pe
Risk Level
Low
Low
Miti ation Strate
Stripping drills, Shut-in drills, Increased
mud wei ht.
Good hole cleaning, PWD Tools, Hole
0 ener Decreased mud wei ht
Reduced um rates Mud rheolo LCM
Trip speeds, Proper hole filling (use of trip
sheets, Pum in out
Lost Circulation
Hole Swabbing on Trips
Low
Moderate
1 C-1 02 L 1 Drilling Hazards Summary
prepared by Scott Lowry
U' '. 08/13/01
I' ,
. hi U I Ì'w¡-.~L
--
~.
-'0
~,
IIo..c
-,
IIfL
~.
e;o:;
r-
See Sheet 1
for Casing
Details
Top of Window at
+/- 5,852' MD,
3,669' TVD
Well # 1C-102, AFE #AK0202
West Sak Multilateral Well
Planned Completion Schematic
Sheet 3 of 4: Upper Lateral Liner Details
(1) Liner Hanger, Baker Flanged Hook Hanger, Size 7-5/8" x 4-1/2",4-1/2",
11.6#, BTC Pin Down
(1) Swivel Sub, Baker, 4-1/2", 11.6#, BTC Box x Pin
(1) Crossover, Baker, 4-1/2", 12.6#, BTC Box x 4-1/2", 12.6#, IBT Pin
(x) Joints 4-1/2" Blank Pipe, 4-1/2", 12.6#, L-BO, IBTM.
(1) ECP /Indicator Sub Assembly, Baker, consisting of:
(1) Handling Pup, 8',4-1/2", 12.6#, L-BO, IBTM Box x BTC Pin
(1) Indicator Profile Sub, Baker, 10K-15K Snap Force,
4-1/2",12.6#, L-80, BTC, Box x Pin
(1) Handling Pup, 6' long, 4-1/2", 12.6#, L-BO, BTC Box x Pin
(1) ECP (External Casing Packer), Baker Model CTC 20' payzone,
4-1/2", 12.6#, L-BO, BTC Box x Box (3.B33 Min ID).
(1) Bottom Sub, Baker, 3' long, 4-1/2", 12.6#, L-BO BTC Pin x
4-1/2", IBTM Pin
(x) Joints 4-1/2" Blank Pipe, 4-1/2", 11.6#, L-BO, IBTM.
Liner Top Packer Set @
+/- 5,944' MD / 3,681' TVD
PHilliPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
(1) ECP /Indicator Sub Assembly, Baker, consisting of:
(1) Handling Pup, B', 4-1/2", 12.6#, L-BO, IBTM Box x BTC Pin
(1) Indicator Profile Sub, Baker, 10K-15K Snap Force,
4-1/2",12.6#, L-BO, BTC, Box x Pin
(1) Handling Pup, 6' long, 4-1/2", 12.6#, L-80, BTC Box x Pin
(1) ECP (External Casing Packer), Baker Model CTC 20' Payzone,
4-1/2", 12.6#, L-BO, BTC Box x Box (3.833 Min ID).
(1) Bottom Sub, Baker, 3' long, 4-1/2", 12.6#, L-BO BTC Pin x
4-1/2", SLHT Pin
(1) Joint 4-1/2" Blank Pipe, Baker, 4-1/2", 11.6#, L-BO, SLHT
---..
(1) Sliding Sleeve, Baker Model 4-1/2" 'CMD', w/3.43" 10, 4-1/2", 11.6# SLHT Box x Pin
(1) Joint 4-1/2" Blank Pipe, Baker, 4-1/2", 11.6#, L-BO, SLHT
(1) Crossover Sub w/4-1/2", 13.5#, SLHT Box x 4",11.6#, SLHT Pin
(1) Joint 4" Blank Pipe, 4", 9.5#, L-BO, SLHT.
(x) joints Screen, 4" x 4-1/2" Baker Excluder 2000, 4", 9.5#, SLHT
alternating eve/}' other joint through the production zone with
(x) joints 4" Blank Pipe, 4", 9.5#, L-BO, SLHT
as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve.
(2) Joints 4" Blank Pipe, 4", 9.5#, L-BO, SLHT Blank Pipe.
(1) Crossover Sub, Baker, 4", 11.6#, SLHT Box x 5", 1B#, SLHT Pin
(1) Joint 5" Blank Pipe, 1B.5' long, Baker, 5", 1B#, L-BO, SLHT, wi Drillable PackoH Bushing
(1) Crossover Sub, Baker, 5", 1B#, SLHT Box x 3-1/2", 9.2# SLHT Pin
~...-
(1) Joint 3-1/2" Bent Pipe, Baker, 3-1/2", 9.2#, L-BO, SLHT, Length 18.5'.
(1) Set Shoe, 3-1/2", Baker Model 'GPV', (4.50" Max 00), 3-1/2", 9.2#, SLHT Box.
------------
------------
------------
-----------
-----------
-----------
6" Open Hole TD:
10,571' MD /3,691' TVD
See Sheet 2
for Lower
Lateral Liner
Details
1 C-1 02 Planned Completion Schematic
Sheet 3 of 4: Upper Lateral Liner Details
prepared by Steve McKeever
August 10, 2001
-----------
-----------
------------
------------
(
(
Well # 1C-102, AFE #AK0202
West Sak Multilateral Well
Planned Completion Schematic
Sheet 4 of 4: Tubing String Details
PHilliPS Alaska, Inc.
A Subsidiary of PHilLIPS PETROLEUM COMPANY
Tree Assembly, Vetco
Gray Gen II, API 13-5/8 -
5000 psi Flange Down x 4-
1/16" 5000 Studded Top,
with Penetrators
Tubing Head Assembly,
Vetco Gray
Tubing Hanger, 4-1/2", Vetco Gray w/
4.909" MCA Top Connection, 4-1/2" L-80
NSCT Pup Joint Down, ESP Power Cable
Penetrator, Heat Trace Penetrator and
TEC Wire Penetrator.
Nabors Rig 245 RKB @ 0'
Eastings: 561,606.18
Northings: 5,968,813.50
Elevation: 101.8' AMSL
(1) Joint Tubing
(x) Pup Joints Tubing, as required to spaceout heat trace.
16" Conductor:
+/- 158' MD
Heat Trace, Centrlift, Surface to +/- 3,000' MD.
(x) Joints Tubing
Tubing String:
4-1/211, 12.6#,
L-80, NSCT
Port Collar:
+/- 1000' MD I 988' TVD
(1) Joint Tubing
(1) Sub, Phoenix Discharge Temperature and Pressure
(1) Pup Joint Tubing, 10ft length
(1) Pup Joint Tubing, 10ft length
(1) Through Tubing Conveyed Electric Submersible Pump (TTCESP)
Assembly, Centrilift, consisting of:
Top of Window:
+/- 5,852' MD I 3,669' TVD
(1) Screen Intake, Centrilift, 5-1/2"
(1) Crossover, Centrilift, 4-1/2", TIC
(1) Tandem Seal Section, Centrilift Model GST3 DB HL PFS
(1) ESP Assembly, Centrilift Model 21 FCNPSH / 140FC2700 (conveyed
through tubing)
(1) Motor, Centrilift, 190 HP 2415/48 KMH-A
(1) Gauge, Phoenix, Model, MS-1 Gauge
(1) Centralizer, Motor, Centrilift, 6.25" 00 to be spaced out +1- 60' MD
above Hook Hanger
Top of Lower Lateral Liner:
+/- 5,944' MD I 3,681' TVD
------------
------------
------------
------------
------------
------------
------------
-----------
-----------
-----------
-----------
-----------
-----------
-----------
D-Sand Lateral 6" Open Hole TD:
10,571' MD /3,691' lVD
7-5/8" Shoe:
+/- 6,410' MD /
3,794' TVD
------------
------------
------------
------------
------------
------------
------------
-----------
-----------
-----------
-----------
-----------
-----------
-----------
B-Sand Lateral 6-3/4" Open Hole TD:
10,585' MD /3,744' TVD
1C-102 Planned Completion Schematic
Sheet 4 of 4: Casing String Details
prepared by Steve McKeever
August 10, 2001
("
PHilliPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
.~.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Charles R. Mallary
Phone (907) 265-6434
Fax: (907) 265-1535
Email: crmalla@ppco.com
RECE\VED
AUG 1 5 2001
August 14, 2001
Alaska Oil & Gas Cons. Commission
Anchorage
Cammy Oechsli Taylor, Chair
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
(907) 279-1433
Re: Application for Permit to Drill, West Sak Multilateral WelllC-l02 L1.
Dear Commissioner Taylor:
Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore multilateral development well to the
West Sak interval from lC Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and
develop the production potential of the West Sak Sands in the vicinity of lC Pad, with two horizontal
penetrations. Previously, the application was submitted for the Permit to Drill the main well bore from
surface to total depth of the horizontal penetration of the West Sak "B" Sand. This application is for the
Permit to Drill the upper lateral, designated lD-l02 Ll, a horizontal penetration of the West Sak "D"
Sand.
The well is designated as a horizontal producer using a 7-5/8" x 7" tapered casing string. A 4-1/2" x 4"
Production Liner will be run and the well will be completed with 4-1/2" tubing and ESP.
The well will be drilled and completed using Nabors Rig 245e. The expected commencement date is
August 27, 2001.
Please find attached for the review of the Commission Form 10-401 and the information required by 20
ACC 25.005.
If you have any questions or require any further information, please contact Steve McKeever at 265-
6826.
OR\G\NAl
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American ExpressQj)
Cash Advance Draft
159
DATE I~ ~vsf 2£01 """".,,
CC!. I- sl' 100. CO I
-----
DOLLARS
Issued by Integrated Payment System, Inc.
Englewood, Colorado
Payable at Norwest Bank of Grand Junction - Downtown, NA
Grand Junction. Colorado
PERIOD ENDING
. ~ : .' II
I: ~ 0 2 ~ 0 0 ... 0 0 I: ~ 5 III 0 ~ ? 5 000 5 ~ b III 0 ~ 5 g
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TRANSMIT AL LETTER CHECK LIST
CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
CHECK 1
STANDARD LETTER
DEVELOPMENT
v
DEVELOPMENT
REDRILL
EXPLORATION
INJECTION WELL
INJECTION WELL
REDRILL
WELLNAME~ /C-/ð2 LI
,
CHECK WHAT APPLIES
ADD-ONS (OPTIONS) "CLUE"
MULTI LATERAL The permit is for a new wellbore segment of existing well
I)~ IC- !~ Permit No,~J-j(ôl API No. o:¿'-:l.~ 03)
(If api number last. two (2) Production should continue to be reported as a function of
digits are between 60-69) the original API number stated above.
rJ:.J. - K' £4 Ie, J¿> 2-- (':20) '/b I)
tJ d 6~ ohPJ 1.1 ~&llf Kl/&J
11'" ~ -*= ð~..Î ../I;¡¡:;;~ I;" ff'-'
~,j ~ ~~.¡ ffæ^ ~/ f\~w-
PILOT HOLE (PH)
ANNULAR ijISPOSAL
(Ý) NO
ANNULAR DISPOSAL
l--> YES
ANNULAR DISPOSAL
THIS WELL
'1\-,,\""
~~"t" ~
~..-..)
In accordance with 20 AAC 25.005(f), all records, data and
logs acquired for the pilot hole must be clearly
differentiated in both name (name on permit plus PH)
and API number (50 -70/80) from
records, data and logs acquired for well (name on permit).
Annular disposal has not been requested. . .
Annular Disposal of drilling wastes will not be approved. . .
Annular Disposal of drilling wastes will not be approved. . .
DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . .
ANNULUS
¥YES+
SPACING EXCEPTION
Enclosed is the approved application for permit to drill the
above referenced well. The permit is approved, subject to
full compliance with 20 AAC 25.055. Approval to perforate
and produce is contingent upon issuance of a conservation
order approving a spacing exception.
(Companv Name) will assume the liability of any protest to
the spacing exception that may occur.
~r<f'."';:'\.O~~">"r>~\. f'O~~ \)~ \'"'-\\\.~ v-)(:\ \.
~(è<è' à(J \ - \<6 \
Templates are located m drive\jody\templates
WELL PERMIT CHECKLIST COMPANY WELL NAME Ie .../0:2.. L J PROGRAM: exp - dev -.K redrtl- serv - wellbore seg x...ann. disposal para req -
FIELD & POOL ~90JSo INIT CLASS LJev /.;t:;J,/1 GEOLAREA ~9~ UNIT# /J/ht"j ON/OFF SHORE nN
ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . N
2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N
3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N
4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N
5. Well located proper distance from drilling unit boundary. . . . Y N
6. Well located proper distance from other wells.. . . . . . . . . N
7. Suffident acreage available' in drilling unit.. . . . . . . . . . . N.
8. If deviated. is wellbore plat induded.. . . . . . . . . . . .'. . N
9. Operator only affected party.. . . . . . . . . . . . . . . . . . N
10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N
11. Permit can be issued without conservation order. . . . . . . . Y N
Þp~ lð0ð) 12. Permit can.be issued without administrative approval.. . . . . Y N
~ 13. Can permit be approved before 15-day wait.. . . . . . . . . . N
ENGINEERING ~i: ~a;~;jE~:t;E~II:~~~~~i~~ri"~g":":"::: ~ ~\,~~\ ok~s~~ ~\,
17. CMT vol adequate to.tie-in long string to suñ csg. . . .. . . . . y ~ - ~ \ \...- -
18. CM~ will co~er all known productive horizons. . . . . '. . . . . ~. 'l:!/. ~~ c.a~~~~'~~
19. Casing designs adequate for C. T. B & permafrost. . . . . . . . N
20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N
21. If a re-drill. has a 10-403 for abandonment been approved. . . .:t-* ~~
22. Adequate well bore separation proposed.. . . . . . . . . . . . <;.:t) N
23. If diverter required. does it meet regulations. . . . . . . . . . ~ ~ ~
. 24. Drilling .fluid program schematic & equip list adequate. . ~ . . N .
25. BOPEs. do they meet regulation. . . . . . . . . . . . . . . . N ,
D~ :~ . 26. BOPE press rating appropriate; test to ~O Dsig. . . N ~~ ~~ ~'> \- Q, \ "S \ \ D~ \
~ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N . \
28. Work will occur without operation shutdbwn. . . . . . . . . . . N. .
29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ ~ ~. "> ~ ~~ ' 'è
30. Permit can be issued w/o hydrogen sulfide measures. . . . .. Y N
31. Data presented on potential overpressure zones. . . . . . . Y N. J! J. Þ1 ~
32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y tJL. - 1"-1 ~
A PR .-D.kT~. 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N .
. ~ 34. Contact name/phone for weekly progress reports [exploratory ani Y N
ANNULAR DISPOSAl35. With proper cementing records. this plan.
(A) will contain waste in a suitable receiving zone; . . . . . . .
(B) will not contaminate freshwater; or cause drilling waste. ..
to surface; . . "
(C) will not impair mechanical integrity .;>f the well used for disposal; Y N
(D) will not damage produdng formation or impair recovery from a Y N
pool; and .
E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N
GEOLOGY: ENGINEERING:,. UIC/Annular COMMISSION:
~þ~' ~~ WM '8~s cor
r'ËN JMt1
GEOLOGY
APPR DATE
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Y N ~Ul--
Y N
Comments/Instructions:
c:\msoffice\wordian\diana\checklist (rev. 11/01/100)
{
~.
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file. ,
To improve the readability of the Well History file and to
simplify finding information. infonnation of this
nature is accumulated at the end of the file under APPEN,DIX.
No special' effort has been made to chronologically
, .
organize this category of information.
~f
(
~~k~:;;:::~~<l:\
Sperry-Sun Drilling Services
LIS Scan Utility
$Revision: 3 $
LisLib $Revision: 4 $
Wed Feb 06 09:44:22 2002
Reel Header
Service name. . . . . . . . . . . . .LISTPE
Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 02 / 0 6
Or ig in. . . . . . . . . . . . . . . . . . . STS
Reel Name............... . UNKNOWN
Continuation Number..... .01
Previous Reel Name...... . UNKNOWN
Comments................ .STS LIS
Writing Library. Scientific Technical Services
Tape Header
Service name. . . . . . . . . . . . .LISTPE
Da t e. . . . . . . . . . . . . . . . . . . . . 02/02 /06
Origin. . . . . . . . . . . . . . . . . . . STS
Tape Name............... . UNKNOWN
Continuation Number..... .01
Previous Tape Name...... . UNKNOWN
Comments................ .STS LIS
Writing Library. Scientific Technical Services
Physical EOF
Comment Record
TAPE HEADER
Kuparuk River Unit
MWD/MAD LOGS
#
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
#
JOB DATA
1C-102 L1
500292303760
PHILLIPS Alaska, Inc.
Sperry-Sun Drilling Services
06-FEB-02
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWDRUN 1
AK-MM-11144
M. HANIK
D. WESTER
MWDRUN 5
AK-MM-11144
R. KRELL
F. HERBERT
MWDRUN 6
AK-MM-11144
R. KRELL
D. WESTER
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
12
11N
10E
1420
600
MSL 0)
101.85
60.60
#
WELL CASING RECORD
1ST STRING
2ND STRING
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
9.875 16.000 158.0
6.000 7.625 5941.0
('
f
3RD STRING
PRODUCTION STRING
#
REMARKS:
1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE
NOTED.
2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD).
3. MWD RUNS 1, 5, AND 6 COMPRISED DIRECTIONAL WITH DUAL
GAMMA RAY (DGR)
UTILIZING GEIGER-MUELLER TUBE DETECTORS,
ELECTROMAGNETIC WAVE
RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE
DRILLING (PWD); MWD
RUNS 5 AND 6 ALSO INCLUDED AT-BIT INCLINATION (ABI).
4. UPHOLE BHI ROP, RESISTIVITY, AND GAMMA RAY DATA WERE
RECEIVED FROM C.
WORLEY (PHILLIPS ALASKA) ON 1/31/02. THESE DATA WERE
CORRECTED/SHIFTED
TO SSDS DATA AND MERGED WITH SSDS MWD RUN 1 DATA. NO
BHI FORMATION
EXPOSURE TIME DATA WERE IDENTIFIED; NO BHI HEADER
DATA ARE INCLUDED.
5. MWD DATA ARE CONSIDERED PDC PER E-MAIL DATED 1/04/02
FROM D. SCHWARTZ,
PHILLIPS ALASKA, INC., QUOTING AUTHORIZATION FROM
GKA GEOSCIENCE GROUP.
6. MWD RUNS 1, 5, and 6 REPRESENT WELL lC-102 Ll WITH
API#: 50-029-23037-60.
THIS WELL LATERAL REACHED A TOTAL DEPTH (TD) OF
10600'MD/3688'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRC = SMOOTHED GAMMA RAY COMBINED.
SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA
SHALLOW SPACING) .
SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW
SPACING) . .
SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM
SPACING) .
SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP
SPACING) .
SFXE = SMOOTHED FORMATION EXPOSURE TIME.
$
File Header
Service name............ .STSLIB.OOl
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .02/02/06
Maximum Physical Record. .65535
File Type.. . . . . . . . . . . . . . .LO
Previous File Name...... .STSLIB.OOO
Comment Record
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted and
DEPTH INCREMENT:
1
clipped curves; all bit runs merged.
.5000
('
#
FILE SUMMARY
PBU TOOL CODE
RPD
RPM
RPS
RPX
GR
ROP
FET
$
START DEPTH
234.0
234.0
234.0
234.0
241.5
286.5
5941.0
STOP DEPTH
10545.0
10545.0
10545.0
10545.0
10538.0
10600.0
10545.0
(
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
$
#
MERGED
PBU
MWD
MWD
MWD
$
DATA SOURCE
TOOL CODE
BIT RUN NO MERGE TOP
1 234.0
5 5971.0
6 9071.0
MERGE BASE
5971.0
9071.0
10600.0
#
REMARKS:
MERGED MAIN PASS.
$
#
Data Format Specification Record
Data Record Type..................O
Data Specification Block Type.....O
Logging Direction. . . . . . . . . . . . . . . . . Down
Optical log depth units.......... .Feet
Data Reference Point............. . Undefined
Frame Spacing.................... .60 .1IN
Max frames per record............ . Undefined
Absent value..................... .-999
Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD FT/H 4 1 68 4 2
GR MWD API 4 1 68 8 3
RPX MWD OHMM 4 1 68 12 4
RPS MWD OHMM 4 1 68 16 5
RPM MWD OHMM 4 1 68 20 6
RPD MWD OHMM 4 1 68 24 7
FET MWD HOUR 4 1 68 28 8
Name Service Unit
DEPT FT
ROP MWD FT/H
GR MWD API
RPX MWD OHMM
RPS MWD OHMM
RPM MWD OHMM
RPD MWD OHMM
FET MWD HOUR
Min
234
0.27
13.53
0.38
0.95
0.06
0.47
0.24
Max
10600
1031.92
138.21
2000
2000
2000
2000
28.55
Mean
5417
181.576
69.4618
52.2369
58.6682
61.7741
66.6949
1.45474
First Reading For Entire File......... .234
Nsam
20733
20246
20594
20623
20623
20623
20623
9209
First
Reading
234
286.5
241.5
234
234
234
234
5941
Last
Reading
10600
10600
10538
10545
10545
10545
10545
10545
~'
Last Reading For Entire File.......... .10600
File Trailer
Service name............ .STSLIB.001
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .02/02/06
Maximum Physical Record. .65535
F i 1 e Type.. . . . . . . . . . . . . . . LO
Next File Name.......... .STSLIB.002
Physical EOF
File Header
Service name............ .STSLIB.002
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .02/02/06
Maximum Physical Record. .65535
File Type. . . . . . . . . . . . . . . .LO
Previous File Name...... .STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
RPM
RPS
RPX
RPD
GR
ROP
$
2
header data for each bit run in separate files.
1
.5000
START DEPTH
234.0
234.0
234.0
234.0
241.5
286.5
STOP DEPTH
5914.0
5914.0
5914.0
5914.0
5907.0
5971.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER ( FT) :
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
25-AUG-01
Insite
66.16
Memory
5941.0
200.0
5941.0
70.3
86.6
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
TOOL NUMBER
PB02031HWRG6
PB02031HWRG6
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
9.875
f
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type..................O
Data Specification Block Type.....O
Logging Direction. . . . . . . . . . . . . . . . . Down
Optical log depth units.......... .Feet
Data Reference Point............. . Undefined
Frame Spacing.................... .60 .1IN
Max frames per record............ . Undefined
Absent value..................... .-999
Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
~t
SPUD
9.60
90.0
9.4
200
4.8
4.500
4.130
4.750
3.500
68.0
74.7
62.0
66.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD010 FT/H 4 1 68 4 2
GR MWD010 API 4 1 68 8 3
RPX MWD010 OHMM 4 1 68 12 4
RPS MWD010 OHMM 4 1 68 16 5
RPM MWD010 OHMM 4 1 68 20 6
RPD MWD010 OHMM 4 1 68 24 7
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 234 5971 3102.5 11475 234 5971
ROP MWD010 FT/H 3.12 1031.92 167.921 10988 286.5 5971
GR MWD010 API 13.53 138.21 70.2478 11332 241.5 5907
RPX MWD010 OHMM 0.38 587.32 46.2194 11361 234 5914
RPS MWD010 OHMM 0.95 853.49 50.8258 11361 234 5914
RPM MWD010 OHMM 0.65 893.6 52.5172 11361 234 5914
RPD MWD010 OHMM 0.62 940.88 57.2172 11361 234 5914
First Reading For Entire File......... .234
Last Reading For Entire File.......... .5971
File Trailer
t
Service name............ .STSLIB.002
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .02/02/06
Maximum Physical Record. .65535
F i 1 e Type. . . . . . . . . . . . . . . . LO
Next File Name.......... .STSLIB.003
Physical EOF
File Header
Service name............ .STSLIB.003
Service Sub Level Name. . .
Version Number.......... .1.0.0
Date of Generation...... .02/02/06
Maximum Physical Record. .65535
File Type..... . . . . . . . . . . . LO
Previous File Name...... .STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
GR
RPD
RPM
RPS
RPX
FET
ROP
$
3
i,(
header data for each bit run in separate files.
5
.5000
START DEPTH
5907.5
5914.5
5914.5
5914.5
5914.5
5941.0
5971.5
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER ( FT) :
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
STOP DEPTH
9006.5
9013.5
9013.5
9013.5
9013.5
9013.5
9071.0
13-SEP-01
Insite
66.16
Memory
9072.0
5941.0
9072.0
70.4
93.4
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
TOOL NUMBER
PB02079HA4
PB02079HA4
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
6.000
(I
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type..................O
Data Specification Block Type.....O
Logging Direction. . . . . . . . . . . . . . . . . Down
Optical log depth units.......... .Feet
Data Reference Point............. . Undefined
Frame Spacing.................... .60 .1IN
Max frames per record............ . Undefined
Absent value..................... .-999
Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
~f
,
BARADRIL-N
9.20
49.0
8.5
15000
4.0
.400
.310
.280
.370
64.0
84.0
58.0
58.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD050 FT/H 4 1 68 4 2
GR MWD050 API 4 1 68 8 3
RPX MWD050 OHMM 4 1 68 12 4
RPS MWD050 OHMM 4 1 68 16 5
RPM MWD050 OHMM 4 1 68 20 6
RPD MWD050 OHMM 4 1 68 24 7
FET MWD050 HOUR 4 1 68 28 8
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 5907.5 9071 7489.25 6328 5907.5 9071
ROP MWD050 FT/H 0.27 1000.47 191.427 6200 5971.5 9071
GR MWD050 API 39.14 123.21 70.1661 6199 5907.5 9006.5
RPX MWD050 OHMM 0.95 1633.05 60.5062 6199 5914.5 9013.5
RPS MWD050 OHMM 1.75 2000 67.9364 6199 5914.5 9013.5
RPM MWD050 OHMM 0.06 2000 73.4437 6199 5914.5 9013.5
RPD MWD050 OHMM 0.47 2000 76.3618 6199 5914.5 9013.5
FET MWD050 HOUR 0.24 13.32 1.34832 6146 5941 9013.5
First Reading For Entire File......... .5907.5
Last Reading For Entire File.......... .9071
File Trailer
Service name............ .STSLIB.003
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .02/02/06
Maximum Physical Record. .65535
File Type. . . . . . . . . . . . . . . .LO
Next File Name.......... .STSLIB.004
Physical EOF
File Header
Service name............ .STSLIB.004
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .02/02/06
Maximum Physical Record. .65535
File Type. . . . . . . . . . . . . . . .LO
Previous File Name...... .STSLIB.003
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
GR
RPD
RPM
RPS
RPX
FET
ROP
$
4
(
header data for each bit run in separate files.
6
.5000
START DEPTH
9007.0
9014.0
9014.0
9014.0
9014.0
9014.0
9071.5
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER ( FT) :
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
STOP DEPTH
10538.0
10545.0
10545.0
10545.0
10545.0
10545.0
10600.0
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
15-SEP-01
Insite
66.16
Memory
10600.0
9072.0
10600.0
88.9
91.7
TOOL NUMBER
PB02079HA4
PB02079HA4
6.000
BARADRIL-N
(
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type..................O
Data Specification Block Type.....O
Logging Direction. . . . . . . . . . . . . . . . . Down
Optical log depth units.......... .Feet
Data Reference Point............. . Undefined
Frame Spacing.................... .60 .1IN
Max frames per record............ . Undefined
Absent value. . . . . . . . . . . . . . . . . . . . . . -999
Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
~.
9.30
43.0
9.0
14500
4.6
.260
.210
.220
.320
71.0
88.0
71.0
71.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD060 FT/H 4 1 68 4 2
GR MWD060 API 4 1 68 8 3
RPX MWD060 OHMM 4 1 68 12 4
RPS MWD060 OHMM 4 1 68 16 5
RPM MWD060 OHMM 4 1 68 20 6
RPD MWD060 OHMM 4 1 68 24 7
FET MWD060 HOUR 4 1 68 28 8
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 9007 10600 9803.5 3187 9007 10600
ROP MWD060 FT/H 2.35 532.23 210.671 3058 9071.5 10600
GR MWD060 API 37.6 90.67 65.1284 3063 9007 10538
RPX MWD060 OHMM 12.29 2000 57.8205 3063 9014 10545
RPS MWD060 OHMM 16.79 225.46 68.9992 3063 9014 10545
RPM MWD060 OHMM 8.38 160.59 72.4915 3063 9014 10545
RPD MWD060 OHMM 13.66 163.16 82.2848 3063 9014 10545
FET MWD060 HOUR 0.27 28.55 1.66829 3063 9014 10545
First Reading For Entire File......... .9007
Last Reading For Entire File.......... .10600
File Trailer
Service name............ .STSLIB.004
Service Sub Level Name. . .
('
Version Number.......... .1.0.0
Date of Generation...... .02/02/06
Maximum Physical Record. .65535
File Type............... .LO
Next File Name.......... .STSLIB.005
Physical EOF
Tape Trailer
Service name. . . . . . . . . . . . .LISTPE
Da t e. . . . . . . . . . . . . . . . . . . . . 02 /02/06
Origin. . . . . . . . . . . . . . . . . . . STS
Tape Name............... . UNKNOWN
Continuation Number..... .01
Next Tape Name.......... . UNKNOWN
Comments................ .STS LIS
Writing Library.
Scientific Technical Services
Reel Trailer
Service name... . . . . . . . . . .LISTPE
Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 02 / 06
Origin. . . . . . . . . . . . . . . . . . . STS
Reel Name............... . UNKNOWN
Continuation Number..... .01
Next Reel Name.......... . UNKNOWN
Comments................ .STS LIS
Writing Library. Scientific Technical Services
Physical EOF
Physical EOF
End Of LIS File
